K. Ueda, Kenya Ono, K. Fuse, Ayako Nonoue, K. Furui, H. Mustapha, K. Tsusaka, K. Furuta, A. Rodriguez-herrera, D. Makimura, T. Manai, Toru Ito
The legacy of conventional fields has resulted in many low permeability reservoirs deemed sub-commercial without an appropriate stimulation strategy. With low permeabilities and potentially heterogeneous reservoir characteristics, an optimal development approach would highly depend on their specific reservoir properties that may well require stimulation methods other than hydraulic fracturing. In this paper, we present a fully integrated characterization and modeling workflow applied to the Kita-Akita oil field in northern Japan, demonstrating the screening process for multiple completion and stimulation methods in a highly heterogeneous, low permeability sandstone reservoir. To select a best completion and stimulation candidate from multiple methods, we constructed an evaluation matrix including the maturity of technologies, applicability to our reservoir, productivity, and economics. Multi-branch type completions such as radial drilling and fishbone drilling, as well as hydraulic fracturing were simulated and subsequently compared based on their productivities. Especially for the radial drilling and the fishbone drilling, a 3D FEM model was built for their complex laterals, and the inflow performances were evaluated with homogenous reservoir properties, respectively. Besides, due to the highly heterogeneous nature of the reservoir, we built a full-physics subsurface model based on a pilot-hole data acquisition and legacy 2D seismic lines. The 3D model served as a canvas to assess reservoir flow and geomechanical behavior, calibrated with production history from past producing wells in the 1950's to 1970's. Based on these models, the best infill drilling location was selected and multiple well completion and stimulation practices were evaluated. Through the screening methodology, the multi-stage hydraulic fracturing was identified as the best suited from an instantaneous productivity perspective. Yet, even though hydraulic fracturing would enhance the accessibility into multiple distinctively isolated sandstones occurring in the deepwater slope channel setting, the treatment costs exceeded the economic threshold significantly in our case. Inflow performance evaluation based on the 3D FEM modeling illustrates multi-branch type completions such as radial drilling and fishbone drilling were identified with a good stimulation skin factor. As a result of 3D simulation study, multi-branch completion was revealed as a technical and economically viable stimulation option in the heterogeneously distributed sandstone reservoirs. The advent of recent completion and stimulation techniques now renders low permeability reservoirs with relatively large development potential. Even with the development challenges quite different from conventional reservoirs, the approach shown in this paper provides a helpful reference for the study and decision-making process when the legacy field needs an optimal stimulation strategy.
{"title":"A Fully Integrated Approach for Screening of Well Completion and Stimulation Methods in Low Permeability, Heterogeneously Distributed Sandstone Reservoirs in the Deepwater Slope Channel, Kita-Akita Oil Field, Northern Japan","authors":"K. Ueda, Kenya Ono, K. Fuse, Ayako Nonoue, K. Furui, H. Mustapha, K. Tsusaka, K. Furuta, A. Rodriguez-herrera, D. Makimura, T. Manai, Toru Ito","doi":"10.2118/192039-MS","DOIUrl":"https://doi.org/10.2118/192039-MS","url":null,"abstract":"\u0000 The legacy of conventional fields has resulted in many low permeability reservoirs deemed sub-commercial without an appropriate stimulation strategy. With low permeabilities and potentially heterogeneous reservoir characteristics, an optimal development approach would highly depend on their specific reservoir properties that may well require stimulation methods other than hydraulic fracturing. In this paper, we present a fully integrated characterization and modeling workflow applied to the Kita-Akita oil field in northern Japan, demonstrating the screening process for multiple completion and stimulation methods in a highly heterogeneous, low permeability sandstone reservoir.\u0000 To select a best completion and stimulation candidate from multiple methods, we constructed an evaluation matrix including the maturity of technologies, applicability to our reservoir, productivity, and economics. Multi-branch type completions such as radial drilling and fishbone drilling, as well as hydraulic fracturing were simulated and subsequently compared based on their productivities. Especially for the radial drilling and the fishbone drilling, a 3D FEM model was built for their complex laterals, and the inflow performances were evaluated with homogenous reservoir properties, respectively. Besides, due to the highly heterogeneous nature of the reservoir, we built a full-physics subsurface model based on a pilot-hole data acquisition and legacy 2D seismic lines. The 3D model served as a canvas to assess reservoir flow and geomechanical behavior, calibrated with production history from past producing wells in the 1950's to 1970's. Based on these models, the best infill drilling location was selected and multiple well completion and stimulation practices were evaluated.\u0000 Through the screening methodology, the multi-stage hydraulic fracturing was identified as the best suited from an instantaneous productivity perspective. Yet, even though hydraulic fracturing would enhance the accessibility into multiple distinctively isolated sandstones occurring in the deepwater slope channel setting, the treatment costs exceeded the economic threshold significantly in our case. Inflow performance evaluation based on the 3D FEM modeling illustrates multi-branch type completions such as radial drilling and fishbone drilling were identified with a good stimulation skin factor. As a result of 3D simulation study, multi-branch completion was revealed as a technical and economically viable stimulation option in the heterogeneously distributed sandstone reservoirs.\u0000 The advent of recent completion and stimulation techniques now renders low permeability reservoirs with relatively large development potential. Even with the development challenges quite different from conventional reservoirs, the approach shown in this paper provides a helpful reference for the study and decision-making process when the legacy field needs an optimal stimulation strategy.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89853849","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}
Building a representative static model for predicting and monitoring performance of coal seam gas fields presents several complex and unique challenges. The individual reservoirs possess very different coal architectures, often with highly complex seam splitting, amalgamating and structural deformation. The objective was to develop an alternative approach which honoured log and core data capturing both the lateral heterogeneity and the vertical signature of the Bowen Basin coals, Central Queensland. In some areas of the Bowen Basin, coals can be thick and laterally continuous; picking the top and base of each seam works well in small models with homogeneous coals. As seam geometries begin to increase in complexity and coals become more heterogeneous in nature with thinner seams in multiple packages, then a net-to-gross (NTG) approach is often more appropriate. Each method has its merits. The former approach describes the reservoir architecture but implies a certain degree of confidence in coal correlation; in a vast field with complex seam splitting and merging with abundant drilling data, it may not be a practical technique. The later method (NTG) disregards coal seam architecture and reservoir connectivity. The proposed workflow is designed to take advantage of both NTG characterization and facies modelling technique using a combined hybrid approach. The process is operating on a relatively coarse layered chronostratigraphic framework in which coal is captured as contiguous discrete-NTG "facies". The utilization of the Truncated Gaussian model ensures the contiguity of facies and mimics transitions between coals and carbonaceous mudstones (or other transitional interburdens). With the adoption of facies vertical proportion trends we are able to replicate a similar coal seam signature laterally away from the well bore. The definition of a categorical coal model allows the proper scaling of seams with different coal quality characteristics. With the successful geocellular model re-construction of two historical Coal Seam Gas (CSG) fields in the Bowen Basin, the discrete-NTG Truncated Gaussian Simulation approach has proven to be a valid alternative CSG modelling technique.
{"title":"Discrete Net-to-Gross Truncated Gaussian Simulation: An Alternative Modelling Approach for CSG Unconventional Reservoirs, Bowen Basin, Eastern Australia","authors":"Simone Rattazzi, A. Hansen","doi":"10.2118/191904-MS","DOIUrl":"https://doi.org/10.2118/191904-MS","url":null,"abstract":"\u0000 Building a representative static model for predicting and monitoring performance of coal seam gas fields presents several complex and unique challenges. The individual reservoirs possess very different coal architectures, often with highly complex seam splitting, amalgamating and structural deformation. The objective was to develop an alternative approach which honoured log and core data capturing both the lateral heterogeneity and the vertical signature of the Bowen Basin coals, Central Queensland.\u0000 In some areas of the Bowen Basin, coals can be thick and laterally continuous; picking the top and base of each seam works well in small models with homogeneous coals. As seam geometries begin to increase in complexity and coals become more heterogeneous in nature with thinner seams in multiple packages, then a net-to-gross (NTG) approach is often more appropriate. Each method has its merits. The former approach describes the reservoir architecture but implies a certain degree of confidence in coal correlation; in a vast field with complex seam splitting and merging with abundant drilling data, it may not be a practical technique. The later method (NTG) disregards coal seam architecture and reservoir connectivity.\u0000 The proposed workflow is designed to take advantage of both NTG characterization and facies modelling technique using a combined hybrid approach. The process is operating on a relatively coarse layered chronostratigraphic framework in which coal is captured as contiguous discrete-NTG \"facies\". The utilization of the Truncated Gaussian model ensures the contiguity of facies and mimics transitions between coals and carbonaceous mudstones (or other transitional interburdens). With the adoption of facies vertical proportion trends we are able to replicate a similar coal seam signature laterally away from the well bore. The definition of a categorical coal model allows the proper scaling of seams with different coal quality characteristics.\u0000 With the successful geocellular model re-construction of two historical Coal Seam Gas (CSG) fields in the Bowen Basin, the discrete-NTG Truncated Gaussian Simulation approach has proven to be a valid alternative CSG modelling technique.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76347204","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}
Zhe Huang, Zhongwei Huang, Yinao Su, Weichang Li, Tianwen Jiang
Radial jet drilling (RJD) is an unconventional drilling technology to drill multiple radial laterals by using a high-pressure liquid jet. It is a cost-effective alternative to bypass damage zones near the wellbore, restimulate the production of old wells and develop the unconventional reservoirs. However, due to the structure of the deflector and the diameter of the radial laterals, traditional well-trajectory measuring tools cannot be applied in the RJD wells. It hinders the conduct of some significant operations. The unknown trajectory is a crucial limitation to further development and field application of the RJD technology. In this paper, except an introduction of RJD technology, a measuring system and a mini-tool were proposed for the attitude measurement and motion state recognition. Based on the navigation theory, a reckoning method of the trajectory was established. After that, an experiment study was carried out to test the performance of the measuring tool and the reckoning method. As results of the experiments, the average errors of the measured lateral length, inclination and azimuth are 8.12%, 5.10% and 5.10% respectively.
{"title":"Where the Laterals Go? A Feasible Way for the Trajectory Measurement of Radial Jet Drilling Wells","authors":"Zhe Huang, Zhongwei Huang, Yinao Su, Weichang Li, Tianwen Jiang","doi":"10.2118/192140-MS","DOIUrl":"https://doi.org/10.2118/192140-MS","url":null,"abstract":"\u0000 Radial jet drilling (RJD) is an unconventional drilling technology to drill multiple radial laterals by using a high-pressure liquid jet. It is a cost-effective alternative to bypass damage zones near the wellbore, restimulate the production of old wells and develop the unconventional reservoirs. However, due to the structure of the deflector and the diameter of the radial laterals, traditional well-trajectory measuring tools cannot be applied in the RJD wells. It hinders the conduct of some significant operations. The unknown trajectory is a crucial limitation to further development and field application of the RJD technology.\u0000 In this paper, except an introduction of RJD technology, a measuring system and a mini-tool were proposed for the attitude measurement and motion state recognition. Based on the navigation theory, a reckoning method of the trajectory was established. After that, an experiment study was carried out to test the performance of the measuring tool and the reckoning method. As results of the experiments, the average errors of the measured lateral length, inclination and azimuth are 8.12%, 5.10% and 5.10% respectively.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"109 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80535053","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}
Alireza Hajizadeh Mobaraki, Raj Deo Tewari, Rahimah A Karim
Uncertainty and risk analysis is an inseparable part of any decision making process in the field development planning. This study sheds light on the available approaches to capture the range of uncertainties but digs deep into the misuses of the probabilistic approach that renders the method difficult and time consuming to implement with little added value for risk mitigation and proper decision making. Probabilistic modeling using dynamic simulation models has been adopted in recent decades to address the variations in forecasted production profiles and to capture the uncertainties. However, there are misuses in the approach that pose questions on the outcome and its meaningfulness. Lack of enough spread in the forecast, history-matched models with physically incorrect parameter ranges/ combinations and models suggesting contradicting development scenarios are among examples. These in turn make the probabilistic forecasting output inconclusive and considering the high computational cost and time required to perform the exercise makes it unattractive to management. In this paper four case studies including mature and green fields have been described and a number of main issues and pitfalls of using probabilistic dynamic modeling in those cases are analyzed. General workflows are then presented for green and brown fields based on experimental design, proxy modeling, optimization and prediction candidates selection that provides solution for proper selection and implementation of the probabilistic dynamic modeling. It is argued that probabilistic modeling can help better capture the uncertainties and reduce the risk in field development planning provided that a fit-for-purpose approach is taken with correct understanding of the data requirement according to the reservoir complexity, the physical processes being modeled and assumptions used in the methodologies and simulation engines. This is in contrast to the attempts to capture the ranges of recoverables based on deterministic high and low cases that is often inefficient as the optimistic high-case of ‘hole-in-one’, may suggest an ideal but not plausible scenario whereas the pessimistic low-case of ‘train-wreck’ may be economically unattractive. The exercise then leaves the companies with the best technical estimate model to make the final call and the numbers from other models are only used for reserve booking purposes. The published papers in the literature include discussions on deterministic vs. probabilistic approaches and selection of base case models, the detailed algorithms and also case studies done using the published methods available in the commercial softwares. This paper however discusses the misuses of the probabilistic dynamic modelling approach and tries to inform the audience of the pitfalls of not understanding the reservoir and/or the tools used in implementing the methods and in this sense it is novel.
{"title":"Embracing Opportunities and Avoiding Pitfalls of Probabilistic Modelling in Field Development Planning","authors":"Alireza Hajizadeh Mobaraki, Raj Deo Tewari, Rahimah A Karim","doi":"10.2118/191959-ms","DOIUrl":"https://doi.org/10.2118/191959-ms","url":null,"abstract":"\u0000 Uncertainty and risk analysis is an inseparable part of any decision making process in the field development planning. This study sheds light on the available approaches to capture the range of uncertainties but digs deep into the misuses of the probabilistic approach that renders the method difficult and time consuming to implement with little added value for risk mitigation and proper decision making.\u0000 Probabilistic modeling using dynamic simulation models has been adopted in recent decades to address the variations in forecasted production profiles and to capture the uncertainties. However, there are misuses in the approach that pose questions on the outcome and its meaningfulness. Lack of enough spread in the forecast, history-matched models with physically incorrect parameter ranges/ combinations and models suggesting contradicting development scenarios are among examples. These in turn make the probabilistic forecasting output inconclusive and considering the high computational cost and time required to perform the exercise makes it unattractive to management. In this paper four case studies including mature and green fields have been described and a number of main issues and pitfalls of using probabilistic dynamic modeling in those cases are analyzed. General workflows are then presented for green and brown fields based on experimental design, proxy modeling, optimization and prediction candidates selection that provides solution for proper selection and implementation of the probabilistic dynamic modeling.\u0000 It is argued that probabilistic modeling can help better capture the uncertainties and reduce the risk in field development planning provided that a fit-for-purpose approach is taken with correct understanding of the data requirement according to the reservoir complexity, the physical processes being modeled and assumptions used in the methodologies and simulation engines. This is in contrast to the attempts to capture the ranges of recoverables based on deterministic high and low cases that is often inefficient as the optimistic high-case of ‘hole-in-one’, may suggest an ideal but not plausible scenario whereas the pessimistic low-case of ‘train-wreck’ may be economically unattractive. The exercise then leaves the companies with the best technical estimate model to make the final call and the numbers from other models are only used for reserve booking purposes.\u0000 The published papers in the literature include discussions on deterministic vs. probabilistic approaches and selection of base case models, the detailed algorithms and also case studies done using the published methods available in the commercial softwares. This paper however discusses the misuses of the probabilistic dynamic modelling approach and tries to inform the audience of the pitfalls of not understanding the reservoir and/or the tools used in implementing the methods and in this sense it is novel.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81297787","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}
This manuscript describes a novel approach to monitor water flood front movement using Proximity Sensing in conjunction with contrast agents. Our technique exploits the presence of resistive layers between reservoirs, which act as a transmission line for electromagnetic signals, to achieve increased propagation range. This work focuses on numerical simulations to evaluate the potential of this approach to monitor water movement in the reservoir under different conditions. A series of 2D axisymmetric numerical simulations were conducted to assess the potential of Proximity Sensing to monitor moving fronts of labeled brine as well as to detect isolated pockets of brine labeled with contrast agents. The study was conducted using layered models that resemble a resistive seal bounded by reservoirs saturated with brine or brine and contrast agents. The effect of magnetic permeability (μ) on signal travel time and amplitude is reported and compared to the effect of electric permittivity (ε). The results show that Proximity Sensing is a suitable technique to detect changes in the μ of reservoirs adjacent to resistive seals. Therefore, our approach can be used in combination with contrast agents, such as Magnetic NanoMappers, to monitor water flood front movement in the reservoir. In addition, this technique can be used to detect isolated pockets of labeled brine, which suggests that injection of slugs of labeled water would be enough for field applications. The observed effect of μ on signal travel time is similar to the trend observed when the electric permittivity of the bounding reservoirs is changed. A significant difference is that increasing μ of the bounding reservoirs appears to reduce signal amplitude while increasing ε has the opposite effect. This result was unexpected and requires further simulations and experimentation to validate this behavior. Proximity Sensing offers a novel approach to address the challenge of electromagnetic propagation in conductive media and paves the way for the development of refined techniques that provide reservoir saturation and water flood front monitoring capabilities with greater resolution.
{"title":"Monitoring Water Flood Front Movement by Propagating High Frequency Pulses Through Subsurface Transmission Lines","authors":"J. M. Felix Servin","doi":"10.2118/191874-ms","DOIUrl":"https://doi.org/10.2118/191874-ms","url":null,"abstract":"\u0000 This manuscript describes a novel approach to monitor water flood front movement using Proximity Sensing in conjunction with contrast agents. Our technique exploits the presence of resistive layers between reservoirs, which act as a transmission line for electromagnetic signals, to achieve increased propagation range. This work focuses on numerical simulations to evaluate the potential of this approach to monitor water movement in the reservoir under different conditions.\u0000 A series of 2D axisymmetric numerical simulations were conducted to assess the potential of Proximity Sensing to monitor moving fronts of labeled brine as well as to detect isolated pockets of brine labeled with contrast agents. The study was conducted using layered models that resemble a resistive seal bounded by reservoirs saturated with brine or brine and contrast agents. The effect of magnetic permeability (μ) on signal travel time and amplitude is reported and compared to the effect of electric permittivity (ε).\u0000 The results show that Proximity Sensing is a suitable technique to detect changes in the μ of reservoirs adjacent to resistive seals. Therefore, our approach can be used in combination with contrast agents, such as Magnetic NanoMappers, to monitor water flood front movement in the reservoir. In addition, this technique can be used to detect isolated pockets of labeled brine, which suggests that injection of slugs of labeled water would be enough for field applications. The observed effect of μ on signal travel time is similar to the trend observed when the electric permittivity of the bounding reservoirs is changed. A significant difference is that increasing μ of the bounding reservoirs appears to reduce signal amplitude while increasing ε has the opposite effect. This result was unexpected and requires further simulations and experimentation to validate this behavior.\u0000 Proximity Sensing offers a novel approach to address the challenge of electromagnetic propagation in conductive media and paves the way for the development of refined techniques that provide reservoir saturation and water flood front monitoring capabilities with greater resolution.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85916824","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}
Many casing failure incidents have been reported in oil and gas fields around the world. These casing failure events can occur not only within reservoirs but also in surrounding formations. Engineers must evaluate risks of casing failure when drilling and completing wells especially in highly compacting reservoirs. However, one of the challenges encountered during the evaluation of casing failure risks is that field-scale stress changes and displacements as a result of drilling wells and producing hydrocarbon from reservoirs must be properly taken into account for casing stability analysis. The objective of this study is to develop an efficient integration method for large-scale reservoir compaction and small-scale casing stability analyses for the evaluation of casing deformation and failure. The numerical model developed in this work is based on 3D elasto-plastic finite element method (FEM). Reservoir compaction and subsidence are analyzed using a large-scale FEM model considering details of geological settings while casing stability is analyzed separately by a small-scale FEM model. The two FEM models are integrated by interpolating displacements calculated by the large-scale model and assigning resultant displacements for boundaries of the small-scale casing stability analysis model. The validation of the proposed integration method is also presented in the paper. Our study results indicate that the integration method presented in this paper significantly improves computational efficiencies on an order of 5 times faster than the conventional simulation method that requires a large number of finite elements for reservoir, surrounding formations, cement, and casing. Also it is demonstrated that the integrated model can be applied to inclined wells completed in highly heterogeneous formations at sufficient accuracy. The field case study also indicates that the risk of casing deformation highly depends on its inclination and the position relative to the compacting formation. The small and large scale coupling method developed in this work helps engineers evaluate casing deformation and failure in various locations in reservoir and surrounding formations in an efficient manner and also develop safe and efficient drilling and completion programs to reduce risk of casing mechanical problems.
{"title":"Efficient Integration Method of Large-Scale Reservoir Compaction and Small-Scale Casing Stability Models for Oilfield Casing Failure Analysis","authors":"Kenta Yamada, K. Furui","doi":"10.2118/192004-MS","DOIUrl":"https://doi.org/10.2118/192004-MS","url":null,"abstract":"\u0000 Many casing failure incidents have been reported in oil and gas fields around the world. These casing failure events can occur not only within reservoirs but also in surrounding formations. Engineers must evaluate risks of casing failure when drilling and completing wells especially in highly compacting reservoirs. However, one of the challenges encountered during the evaluation of casing failure risks is that field-scale stress changes and displacements as a result of drilling wells and producing hydrocarbon from reservoirs must be properly taken into account for casing stability analysis. The objective of this study is to develop an efficient integration method for large-scale reservoir compaction and small-scale casing stability analyses for the evaluation of casing deformation and failure.\u0000 The numerical model developed in this work is based on 3D elasto-plastic finite element method (FEM). Reservoir compaction and subsidence are analyzed using a large-scale FEM model considering details of geological settings while casing stability is analyzed separately by a small-scale FEM model. The two FEM models are integrated by interpolating displacements calculated by the large-scale model and assigning resultant displacements for boundaries of the small-scale casing stability analysis model. The validation of the proposed integration method is also presented in the paper.\u0000 Our study results indicate that the integration method presented in this paper significantly improves computational efficiencies on an order of 5 times faster than the conventional simulation method that requires a large number of finite elements for reservoir, surrounding formations, cement, and casing. Also it is demonstrated that the integrated model can be applied to inclined wells completed in highly heterogeneous formations at sufficient accuracy. The field case study also indicates that the risk of casing deformation highly depends on its inclination and the position relative to the compacting formation.\u0000 The small and large scale coupling method developed in this work helps engineers evaluate casing deformation and failure in various locations in reservoir and surrounding formations in an efficient manner and also develop safe and efficient drilling and completion programs to reduce risk of casing mechanical problems.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84537593","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}
Ming Eryang, Tao Li, Yiliang Li, X. Pei, Zhongxian Hao, Guo Tong
In recent years, the flexible coiled composite pipe (FCCP) has developed rapidly in China. Because of its merit about chemical inertness, it has been introduced to onshore oilfields to endurance some severe situations, such as serving as tubing in corrosive and waxy oil wells, as tubing in scaling water injection wells or as surface gathering pipelines, especially suitable for mountainous areas. This paper will introduce the development status of FCCP in different applications. According to our research and development, for FCCP structure manufacture, there are two main technical routes in China, non-adhesive pipe and adhesive pipe. These two kinds of pipe meet the merits of FCCP, however, there are some differences in technical parameters. Obviously, non-adhesive pipe has smaller bending radius, but the integrity of adhesive pipe is better which is good for fitting installation. In this technical stage, the FCCP has been applied in surface gathering system, general water injection system and rodless artificial lift system. For surface gathering system, this is the most mature application of this technology. It has been laid over 30,000 kilometers. Compared with steel pipe, the equipment of FCCP is simple and high laying efficiency. For general water injection system, the FCCP replaces steel pipe by high working efficiency and long endurance. It has been applied more than 80 wells. For rodless artificial lift system, there are almost 60 wells applied FCCP. It is the severest running condition for FCCP with high temperature, high wellbore pressure and high varies suspension force. This application reveals the advancement of FCCP by twining cables inside the pipe body and adding functions of real-time monitoring and heating. Two typical applications are serving as tubing in cold heavy oil production and acid gas corrosion oil well. The application of FCCP has made great progress. But there are several key issues that need to be resolved in the future research. First, there is lack of post evaluation of performance. Second, the limit of material working temperature shrinks the application scope. Third, the external pressure resistance is limited. This paper shows the applications of flexible coiled composite pipe in onshore oilfields of China in the past 5 years, including a summary of technical experience, and proposing the goal of further research.
{"title":"The Application of Flexible Coiled Composite Pipe in Onshore Oilfields in China","authors":"Ming Eryang, Tao Li, Yiliang Li, X. Pei, Zhongxian Hao, Guo Tong","doi":"10.2118/191924-MS","DOIUrl":"https://doi.org/10.2118/191924-MS","url":null,"abstract":"\u0000 In recent years, the flexible coiled composite pipe (FCCP) has developed rapidly in China. Because of its merit about chemical inertness, it has been introduced to onshore oilfields to endurance some severe situations, such as serving as tubing in corrosive and waxy oil wells, as tubing in scaling water injection wells or as surface gathering pipelines, especially suitable for mountainous areas. This paper will introduce the development status of FCCP in different applications.\u0000 According to our research and development, for FCCP structure manufacture, there are two main technical routes in China, non-adhesive pipe and adhesive pipe. These two kinds of pipe meet the merits of FCCP, however, there are some differences in technical parameters. Obviously, non-adhesive pipe has smaller bending radius, but the integrity of adhesive pipe is better which is good for fitting installation. In this technical stage, the FCCP has been applied in surface gathering system, general water injection system and rodless artificial lift system.\u0000 For surface gathering system, this is the most mature application of this technology. It has been laid over 30,000 kilometers. Compared with steel pipe, the equipment of FCCP is simple and high laying efficiency. For general water injection system, the FCCP replaces steel pipe by high working efficiency and long endurance. It has been applied more than 80 wells. For rodless artificial lift system, there are almost 60 wells applied FCCP. It is the severest running condition for FCCP with high temperature, high wellbore pressure and high varies suspension force. This application reveals the advancement of FCCP by twining cables inside the pipe body and adding functions of real-time monitoring and heating. Two typical applications are serving as tubing in cold heavy oil production and acid gas corrosion oil well. The application of FCCP has made great progress. But there are several key issues that need to be resolved in the future research. First, there is lack of post evaluation of performance. Second, the limit of material working temperature shrinks the application scope. Third, the external pressure resistance is limited.\u0000 This paper shows the applications of flexible coiled composite pipe in onshore oilfields of China in the past 5 years, including a summary of technical experience, and proposing the goal of further research.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75781673","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}
Honglan Zou, M. Cui, He Liu, C. Liang, Ping-li Liu, Heng Xue, Pei-shan Wang
Focusing on the characteristics of long horizontal interval (>800m) and strong heterogeneity of complex carbonate reservoir, this paper puts forward a high efficiency uneven acid distribution technology, consequently solving the problems of high large scale and financially-challenged acidizing result. It takes the damage profile in productivity established stage or liquid production profile in the stable production stage for horizontal wells as the designed core, and selects optimal injecting point and interval in the long-interval horizontal well to maximize stimulation effect with minimal acid. This paper establishes an integrated mathematical model for the quantitative analysis of non-uniform damage of horizontal well simulated acidizing diverting and the acid-etched wormholes propagation for complicated carbonate reservoir. Besides, the matching technological methods and strategies, such as whole or local selective acid injection using coil tubing, inert liquid injection in the annulus, and the secondary segmented acidizing displacement, were presented. This technology has been applied in the AHDEB and HALFAYA oilfield, completing 296 wells acidizing treatments. The results demonstrated that the average acidizing volume decreased from 500-900m3 to 150m3 and production significantly increased.
{"title":"An Uneven Acid Injection Technology for Long-Lateral Horizontal Wells in Complex Carbonate Reservoirs: Simulation, Optimisation and Practice","authors":"Honglan Zou, M. Cui, He Liu, C. Liang, Ping-li Liu, Heng Xue, Pei-shan Wang","doi":"10.2118/191991-MS","DOIUrl":"https://doi.org/10.2118/191991-MS","url":null,"abstract":"\u0000 Focusing on the characteristics of long horizontal interval (>800m) and strong heterogeneity of complex carbonate reservoir, this paper puts forward a high efficiency uneven acid distribution technology, consequently solving the problems of high large scale and financially-challenged acidizing result. It takes the damage profile in productivity established stage or liquid production profile in the stable production stage for horizontal wells as the designed core, and selects optimal injecting point and interval in the long-interval horizontal well to maximize stimulation effect with minimal acid.\u0000 This paper establishes an integrated mathematical model for the quantitative analysis of non-uniform damage of horizontal well simulated acidizing diverting and the acid-etched wormholes propagation for complicated carbonate reservoir.\u0000 Besides, the matching technological methods and strategies, such as whole or local selective acid injection using coil tubing, inert liquid injection in the annulus, and the secondary segmented acidizing displacement, were presented.\u0000 This technology has been applied in the AHDEB and HALFAYA oilfield, completing 296 wells acidizing treatments. The results demonstrated that the average acidizing volume decreased from 500-900m3 to 150m3 and production significantly increased.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"11 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78216134","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}
Roumen Dimitrov Sankoff, Behrooz Bijani, Gianluca Di Martino, Julie Watson, C. S. Marshall
The intent of this work is to outline the workflow that engineers can apply in the selection and modelling of inflow control devices (ICDs) for use in completion design. It provides a step-by-step guide and examples of how to address the key challenges in the field of modelling of ICDs, namely: the choice of ICD technology that is most suitable for the particular well; the process of building a custom ICD performance model and import into the reservoir simulator; considerations in setting up the simulation model; and, verification of the results. The paper highlights the risk of using empirical ICD models, available in reservoir simulators, in the early stages of evaluating inflow control technology. It then demonstrates that the decision on whether or not an inflow control is required, and what type, can be made without resorting to these built-in empirical models in reservoir simulators. The paper introduces a new approach to evaluation, comparison and modelling of inflow control devices of different types and geometry. Focused on simplicity and accuracy, the method of ICD characterisation is described, as is how to use this characterisation to generate input to the reservoir simulator. A method for verification of the output from the reservoir simulator is also presented. The application of this modelling approach is illustrated through a case study on evaluating inflow control technology in a mature oil reservoir.
{"title":"Modelling of Inflow Control Devices: From the Flow Loop to the Simulator","authors":"Roumen Dimitrov Sankoff, Behrooz Bijani, Gianluca Di Martino, Julie Watson, C. S. Marshall","doi":"10.2118/192116-MS","DOIUrl":"https://doi.org/10.2118/192116-MS","url":null,"abstract":"\u0000 The intent of this work is to outline the workflow that engineers can apply in the selection and modelling of inflow control devices (ICDs) for use in completion design. It provides a step-by-step guide and examples of how to address the key challenges in the field of modelling of ICDs, namely: the choice of ICD technology that is most suitable for the particular well; the process of building a custom ICD performance model and import into the reservoir simulator; considerations in setting up the simulation model; and, verification of the results.\u0000 The paper highlights the risk of using empirical ICD models, available in reservoir simulators, in the early stages of evaluating inflow control technology. It then demonstrates that the decision on whether or not an inflow control is required, and what type, can be made without resorting to these built-in empirical models in reservoir simulators.\u0000 The paper introduces a new approach to evaluation, comparison and modelling of inflow control devices of different types and geometry. Focused on simplicity and accuracy, the method of ICD characterisation is described, as is how to use this characterisation to generate input to the reservoir simulator. A method for verification of the output from the reservoir simulator is also presented.\u0000 The application of this modelling approach is illustrated through a case study on evaluating inflow control technology in a mature oil reservoir.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80011450","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Ekkawong, Wich Huengwattanakul, Pichaya Ruthairung, A. Rittirong, S. Vitoonkijvanich, Kasama Itthisawatpan
Optimal well placement remains both highly challenging and significantly important in the E&P business since they impact field development decision making. Conventionally, well placement is performed manually based on well spacing, which may not capture the effect of reservoir geology effectively, especially in cases of high reservoir heterogeneities. Modern techniques tackle this problem by treating well locations as discrete optimisation problems through reservoir simulations, and thus apply heuristic algorithms to search for optimal well locations. However, these methods require considerable computational effort, which forestall any efforts at novel techniques in searching to for global optimal solutions. This paper presents an innovative well placement optimisation workflow to minimize the calculation time of simulation using drainage volume via streamlines time-of-flight. A reservoir simulation is run for a short period of time to acquire streamlines for all proposed well locations. The time-of-flight property, along streamlines, indicates the theoretical time required for a theoretical tracer particle to move along each streamline to a producer (pressure sink). The time-of-flight, together with reservoir properties, are then used to calculate the hydrocarbon drainage volume from each producer. In which, it is the key parameter to suggest that how much hydrocarbon can move to wells with a given production period. This workflow will search for optimal well locations to maximize the hydrocarbon drainage volume with a given number of wells. The approach translates reservoir simulation to numerical matrix union optimisation, which can be carried out at an extremely fast computational speed (less than a second for a single iteration). The expedited calculation efficiency allows exhaustive search algorithms to evaluate millions of possible well combinations and can, consequently, guarantee a global optimal solution. The workflow has been conceptually proven with a synthetic 2D simulation model, providing a pattern-like scheme to mimic the conventional approach. Furthermore, it has been successfully tested with field scale reservoir simulations. The algorithm demonstrates the advantages of optimized well-placement over conventional methods without much of an increased computational burden. The workflow is also designed to be automated with a simple user-interaction via MATLAB and MS-Excel; namely, the SMARTDRAIN package. This allows engineers/geologists to implement it as a generic workflow without requiring extensive knowledge in mathematical algorithms. With such calculation efficiency and improved optimal solution, this approach can be applied as a new well placement optimisation standard that would add competitive value in field development planning and optimisation.
{"title":"SMARTDRAIN: An Intelligent Workflow for Well-Placement Optimisation by Integrating Streamlines Time-of-Flight and Exhaustive Search Algorithm","authors":"P. Ekkawong, Wich Huengwattanakul, Pichaya Ruthairung, A. Rittirong, S. Vitoonkijvanich, Kasama Itthisawatpan","doi":"10.2118/192036-MS","DOIUrl":"https://doi.org/10.2118/192036-MS","url":null,"abstract":"\u0000 Optimal well placement remains both highly challenging and significantly important in the E&P business since they impact field development decision making. Conventionally, well placement is performed manually based on well spacing, which may not capture the effect of reservoir geology effectively, especially in cases of high reservoir heterogeneities. Modern techniques tackle this problem by treating well locations as discrete optimisation problems through reservoir simulations, and thus apply heuristic algorithms to search for optimal well locations. However, these methods require considerable computational effort, which forestall any efforts at novel techniques in searching to for global optimal solutions.\u0000 This paper presents an innovative well placement optimisation workflow to minimize the calculation time of simulation using drainage volume via streamlines time-of-flight. A reservoir simulation is run for a short period of time to acquire streamlines for all proposed well locations. The time-of-flight property, along streamlines, indicates the theoretical time required for a theoretical tracer particle to move along each streamline to a producer (pressure sink). The time-of-flight, together with reservoir properties, are then used to calculate the hydrocarbon drainage volume from each producer. In which, it is the key parameter to suggest that how much hydrocarbon can move to wells with a given production period. This workflow will search for optimal well locations to maximize the hydrocarbon drainage volume with a given number of wells.\u0000 The approach translates reservoir simulation to numerical matrix union optimisation, which can be carried out at an extremely fast computational speed (less than a second for a single iteration). The expedited calculation efficiency allows exhaustive search algorithms to evaluate millions of possible well combinations and can, consequently, guarantee a global optimal solution. The workflow has been conceptually proven with a synthetic 2D simulation model, providing a pattern-like scheme to mimic the conventional approach. Furthermore, it has been successfully tested with field scale reservoir simulations. The algorithm demonstrates the advantages of optimized well-placement over conventional methods without much of an increased computational burden.\u0000 The workflow is also designed to be automated with a simple user-interaction via MATLAB and MS-Excel; namely, the SMARTDRAIN package. This allows engineers/geologists to implement it as a generic workflow without requiring extensive knowledge in mathematical algorithms. With such calculation efficiency and improved optimal solution, this approach can be applied as a new well placement optimisation standard that would add competitive value in field development planning and optimisation.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84859188","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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