K. Saleh, C. Cavalleri, Hugo Espinosa, Mohamed Ghanim, M. Galal, Renata Gomes, Aly Morad
Recent advancement in logging technology and data analytics enables measuring a comprehensive set of formation petrophysical properties and rock composition in cased-hole environments. Using state-of-art pulsed neutron logging technology and processing algorithms enables recording capture and inelastic elemental spectroscopy for rock elemental concentrations, including total organic carbon, detailed mineralogy and matrix properties, simultaneously to sigma and other neutron-based outputs. The integration of the interpreted lithology from cased-hole elemental spectroscopy data with electrofacies from high-resolution imaging tools recorded in the open-hole provides the characterization of heterogeneity challenges by building a synthetic core in old wells with limited data gathering from open-hole logging or absence of conventional coring. An effective way to incorporate those measurements has been developed and adapted to the use of cased-hole spectroscopy logs. The dry weight elemental fractions measured by the advanced pulse neutron technology are corrected for wellbore contribution and converted into dry weight mineralogical outputs. Using an automated processing workflow converts the capture and inelastic gamma-ray yields from the energy spectrum measured behind casing into the dry weight of elements and mineral fractions in the formation. The computed mineralogical outputs are then defined based on a standardized ternary diagram approach to developing dry-weight mineralogy-based lithofacies. This classification is then combined with the calibrated micro-resistivity image data collected during the open-hole logs evaluation to present a high-resolution rock typing (after Kumar & Kear). The resulting log is dry weight mineralogy-based high-resolution lithofacies that contain vital information to support geological and petrophysical reserves modeling adjustments during development and production. The paper demonstrates the applicability of the method to cased-hole environments in fields with mixed lithology and complex geological background. Once a robust lithofacies classification is achieved, this is applied for detailed stratigraphic analysis, well-to-well correlation, or refined static reservoir modeling. A standardized mineral-based facies scheme guides the selection of higher completion-quality intervals, otherwise difficult to define in old wells with limited original evaluation. Besides, thin beds that were previously bypassed can be detected and characterized for high-resolution net pay calculation leveraging the high-resolution lithofacies output from this approach. The lithofacies classification (synthetic core) provides important input to the study of reservoir connectivity in the development phase and production optimization. Moreover, a synthetic core description would be critical when reassessing mature fields and defining completion and production strategies where core data is not available. The approach and workflow can be impl
{"title":"Slim Pulsed Neutron Spectroscopy Integrated with Wellbore Imaging to Provide Synthetic Core in Slim Boreholes and Cased-Hole Environment","authors":"K. Saleh, C. Cavalleri, Hugo Espinosa, Mohamed Ghanim, M. Galal, Renata Gomes, Aly Morad","doi":"10.2118/203478-ms","DOIUrl":"https://doi.org/10.2118/203478-ms","url":null,"abstract":"Recent advancement in logging technology and data analytics enables measuring a comprehensive set of formation petrophysical properties and rock composition in cased-hole environments. Using state-of-art pulsed neutron logging technology and processing algorithms enables recording capture and inelastic elemental spectroscopy for rock elemental concentrations, including total organic carbon, detailed mineralogy and matrix properties, simultaneously to sigma and other neutron-based outputs. The integration of the interpreted lithology from cased-hole elemental spectroscopy data with electrofacies from high-resolution imaging tools recorded in the open-hole provides the characterization of heterogeneity challenges by building a synthetic core in old wells with limited data gathering from open-hole logging or absence of conventional coring.\u0000 An effective way to incorporate those measurements has been developed and adapted to the use of cased-hole spectroscopy logs. The dry weight elemental fractions measured by the advanced pulse neutron technology are corrected for wellbore contribution and converted into dry weight mineralogical outputs. Using an automated processing workflow converts the capture and inelastic gamma-ray yields from the energy spectrum measured behind casing into the dry weight of elements and mineral fractions in the formation. The computed mineralogical outputs are then defined based on a standardized ternary diagram approach to developing dry-weight mineralogy-based lithofacies. This classification is then combined with the calibrated micro-resistivity image data collected during the open-hole logs evaluation to present a high-resolution rock typing (after Kumar & Kear). The resulting log is dry weight mineralogy-based high-resolution lithofacies that contain vital information to support geological and petrophysical reserves modeling adjustments during development and production.\u0000 The paper demonstrates the applicability of the method to cased-hole environments in fields with mixed lithology and complex geological background. Once a robust lithofacies classification is achieved, this is applied for detailed stratigraphic analysis, well-to-well correlation, or refined static reservoir modeling. A standardized mineral-based facies scheme guides the selection of higher completion-quality intervals, otherwise difficult to define in old wells with limited original evaluation. Besides, thin beds that were previously bypassed can be detected and characterized for high-resolution net pay calculation leveraging the high-resolution lithofacies output from this approach. The lithofacies classification (synthetic core) provides important input to the study of reservoir connectivity in the development phase and production optimization. Moreover, a synthetic core description would be critical when reassessing mature fields and defining completion and production strategies where core data is not available.\u0000 The approach and workflow can be impl","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127425764","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}
A. Alshalabi, Haitham Al Saadi, F. Maire, T. Thomas, Talla Gueye, Fatema Al Amiri
Reservoir X is a giant oil reservoir of 30×10 Km2 developed since 1973 using peripheral water injection. A major review study was done in 2016 highlighted major reservoir challenges that need to be managed and mitigated. The main challenges are (a) reservoir pressure decline in the central area (b) advancement of water cut/water conning (c) increased number of inactive strings (d) improper distribution of production offtake (e) inefficiency of current injection scheme. Consequently, reservoir deliverable potential has continuously dropped with increasing inactive strings threatening the attainment of the field mandated production target. This requires a major shift in our reservoir management strategies and best practices to cope with these challenges. In this paper, a case study for reservoir management in a mature carbonate reservoir with its detailed methodology is presented. An intensive and integrated technical work was conducted to (a) regain the target technical rate of 20% (300Mbpd) (b) arrest the pressure decline (c) implementation of a more efficient long-term plan to increase reservoir pressure and to maximize ultimate recovery. A detailed approach was developed which consisted of short, mid and longterm actions. This approach involves (a) re-prioritization of infill drilling through weighted ranking (b) pressure recovery implementation strategy through sectorization, re-balancing of production offtake and improving water injection efficiency (c) sector based evaluation using simulation/streamlines/data analysis for the voidage replacement (e) water injection optimization with the help of new peripheral water injectors, increased water injection availability (New clusters and network debottlenecking) and new Water Injection scheme (Mid Flank water injectors) (f) tracking the implementation of the Pressure Recovery Plan with a dedicated and tailored monitoring dashboard. Through this integrated approach a portfolio of wells is selected and ranked that help in achieving the objectives of the reservoir development efficiently and the 20% Technical Rate achievement. The sector wise analysis and tracking approach enabled in arresting the pressure decline in the crestal area and ensured that the focus remained on the recovering pressure in the worst affected areas of the reservoir while meeting the production requirements. Another important outcome of this work was to drive a slew of initiatives related to the improvement of water injection efficiency that is a necessary requirement to recover the pressure in the crestal area. This reservoir management methodology and framework put in place provides a platform to continuously integrate the inputs (production/injection; VRR; pressure) and develop understanding from the different disciplines of the reservoir development to monitor and manage the reservoir in and efficient and timely manner.
{"title":"A Major Shift In Reservoir Management Strategies And Best Practices In A Mature Reservoir To Overcome The Current Reservoir Challenges: Case Study","authors":"A. Alshalabi, Haitham Al Saadi, F. Maire, T. Thomas, Talla Gueye, Fatema Al Amiri","doi":"10.2118/203313-ms","DOIUrl":"https://doi.org/10.2118/203313-ms","url":null,"abstract":"\u0000 Reservoir X is a giant oil reservoir of 30×10 Km2 developed since 1973 using peripheral water injection. A major review study was done in 2016 highlighted major reservoir challenges that need to be managed and mitigated. The main challenges are (a) reservoir pressure decline in the central area (b) advancement of water cut/water conning (c) increased number of inactive strings (d) improper distribution of production offtake (e) inefficiency of current injection scheme. Consequently, reservoir deliverable potential has continuously dropped with increasing inactive strings threatening the attainment of the field mandated production target. This requires a major shift in our reservoir management strategies and best practices to cope with these challenges.\u0000 In this paper, a case study for reservoir management in a mature carbonate reservoir with its detailed methodology is presented. An intensive and integrated technical work was conducted to (a) regain the target technical rate of 20% (300Mbpd) (b) arrest the pressure decline (c) implementation of a more efficient long-term plan to increase reservoir pressure and to maximize ultimate recovery. A detailed approach was developed which consisted of short, mid and longterm actions. This approach involves (a) re-prioritization of infill drilling through weighted ranking (b) pressure recovery implementation strategy through sectorization, re-balancing of production offtake and improving water injection efficiency (c) sector based evaluation using simulation/streamlines/data analysis for the voidage replacement (e) water injection optimization with the help of new peripheral water injectors, increased water injection availability (New clusters and network debottlenecking) and new Water Injection scheme (Mid Flank water injectors) (f) tracking the implementation of the Pressure Recovery Plan with a dedicated and tailored monitoring dashboard.\u0000 Through this integrated approach a portfolio of wells is selected and ranked that help in achieving the objectives of the reservoir development efficiently and the 20% Technical Rate achievement. The sector wise analysis and tracking approach enabled in arresting the pressure decline in the crestal area and ensured that the focus remained on the recovering pressure in the worst affected areas of the reservoir while meeting the production requirements. Another important outcome of this work was to drive a slew of initiatives related to the improvement of water injection efficiency that is a necessary requirement to recover the pressure in the crestal area. This reservoir management methodology and framework put in place provides a platform to continuously integrate the inputs (production/injection; VRR; pressure) and develop understanding from the different disciplines of the reservoir development to monitor and manage the reservoir in and efficient and timely manner.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115288061","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}
Maniesh Singh, G. Makarychev, H. Mustapha, D. Voleti, R. Akkurt, K. Daghar, A. Mawlod, Khalid Ibrahim Al Marzouqi, Sami Shehab, Alaa Maarouf, Obeida El Jundi, A. Razouki
Mature field operators collect log data for tens of years. Collection of log dataset include various generation and multiple vintages of logging tool from multiple vendors. Standard approach is to correct the logs for various artefacts and normalize the logs over a field scale. Manually conducting this routine is time consuming and subjective. The objective of the study was to create a machine learning (ML) assisted tool for logs in a giant Lower Cretaceous Carbonate Onshore field in Abu Dhabi, UAE to automatically perform data QC, bad data identification and log reconstruction (correcting for borehole effects, filling gaps, cleaning spikes, etc.) of Quad Combo well logs. The study targets Quad Combo logs acquired since mid-60's. Machine learning algorithm was trained on 50 vertical wells, spread throughout the structure of the field. The workflow solution consists of several advanced algorithms guided by domain knowledge and physics based well logs correlation, all embedded in an ML-data-driven environment. The methodology consists of the following steps: oOutliers detection and complete data clustering.oSupervised ML to map outliers to clusters.oRandom Forest based ML training by clusters, by logs combination on complete data.oSaved models are applied back to the whole data including outliers and sections with one or several logs missing.oValidation and Blind test of results.oModels can be stored and re-used for prediction on new data. The ML tool demonstrated its effectiveness while correcting logs for outliers’ like Depth Offsets between logs, identifying Erroneous readings, logs prediction for absent data and Synthetic logs corrections. The tool has a tendency to harmonize logs. First test demonstrated robustness of the selected algorithm for outliers’ detection. It cleaned data from most of contamination, while keeping good but statistically underrepresented logs readings. Clustering algorithm was enhanced to supplement cluster assignment by extraction of the corresponding probabilities that were used as a cut-off value and utilized for a mixture of different ML models results. This application made results more realistic in the intervals where clustering was problematic and at the transition between different clusters. Several intervals of bad and depth shifted logs corrections were noticed. Outliers’ corrections for these logs was performed the way that at Neutron-Density or Neutron-Sonic cross-plots points were moved towards expected lithology lines. Algorithm could pick-up hidden outliers (such as synthetic logs) and edited the logs to make it look intuitively natural to a human analyst. The work successfully demonstrated effectiveness of ML tool for log editing in a complex environment working on a big dataset that was subject of manual editing and has number of hidden outliers. This strong log quality assurance further assisted in building Rock Typing based Static Model in complex and diagenetically altered Carbonates.
{"title":"Machine Learning Assisted Petrophysical Logs Quality Control, Editing and Reconstruction","authors":"Maniesh Singh, G. Makarychev, H. Mustapha, D. Voleti, R. Akkurt, K. Daghar, A. Mawlod, Khalid Ibrahim Al Marzouqi, Sami Shehab, Alaa Maarouf, Obeida El Jundi, A. Razouki","doi":"10.2118/202977-ms","DOIUrl":"https://doi.org/10.2118/202977-ms","url":null,"abstract":"\u0000 Mature field operators collect log data for tens of years. Collection of log dataset include various generation and multiple vintages of logging tool from multiple vendors. Standard approach is to correct the logs for various artefacts and normalize the logs over a field scale. Manually conducting this routine is time consuming and subjective. The objective of the study was to create a machine learning (ML) assisted tool for logs in a giant Lower Cretaceous Carbonate Onshore field in Abu Dhabi, UAE to automatically perform data QC, bad data identification and log reconstruction (correcting for borehole effects, filling gaps, cleaning spikes, etc.) of Quad Combo well logs.\u0000 The study targets Quad Combo logs acquired since mid-60's. Machine learning algorithm was trained on 50 vertical wells, spread throughout the structure of the field.\u0000 The workflow solution consists of several advanced algorithms guided by domain knowledge and physics based well logs correlation, all embedded in an ML-data-driven environment. The methodology consists of the following steps: oOutliers detection and complete data clustering.oSupervised ML to map outliers to clusters.oRandom Forest based ML training by clusters, by logs combination on complete data.oSaved models are applied back to the whole data including outliers and sections with one or several logs missing.oValidation and Blind test of results.oModels can be stored and re-used for prediction on new data.\u0000 The ML tool demonstrated its effectiveness while correcting logs for outliers’ like Depth Offsets between logs, identifying Erroneous readings, logs prediction for absent data and Synthetic logs corrections. The tool has a tendency to harmonize logs. First test demonstrated robustness of the selected algorithm for outliers’ detection. It cleaned data from most of contamination, while keeping good but statistically underrepresented logs readings.\u0000 Clustering algorithm was enhanced to supplement cluster assignment by extraction of the corresponding probabilities that were used as a cut-off value and utilized for a mixture of different ML models results. This application made results more realistic in the intervals where clustering was problematic and at the transition between different clusters.\u0000 Several intervals of bad and depth shifted logs corrections were noticed. Outliers’ corrections for these logs was performed the way that at Neutron-Density or Neutron-Sonic cross-plots points were moved towards expected lithology lines. Algorithm could pick-up hidden outliers (such as synthetic logs) and edited the logs to make it look intuitively natural to a human analyst.\u0000 The work successfully demonstrated effectiveness of ML tool for log editing in a complex environment working on a big dataset that was subject of manual editing and has number of hidden outliers. This strong log quality assurance further assisted in building Rock Typing based Static Model in complex and diagenetically altered Carbonates.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"191 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116667113","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The objective of this paper is to showcase the successful and innovative troubleshooting data analysis techniques in one of the gas compression systems in upstream gas oil separation plants (GOSP-A). The gas compression system using gas compressors, dry gas seal systems and due point controls is used in almost all of upstream operation. These proven data analysis techniques were used to tackle major and chronic issues associated with gas compression system operation that lead to excessive flaring, mechanical seal failures, and off-specification products. Dry Gas mechanical seals are an important key element in gas compression and its lifetime represents a concern to the operation personnel. Most gas compression systems have a mechanical seal lifetime of 2 years which in some cases limit production, increase the potential of unnecessary flaring and increase OPEX significantly. In this paper, comprehensive data analysis of the potential root causes that aggravate undesired premature mechanical seal failures and off-specification gas products will be discussed along with solutions to minimize expected impact. For example, improper gas conditioning that feeds dry gas mechanical seals increase the risk of premature failures. Additionally, improper product specification in some applications have been found to promote seal failures and incur additional flaring which is both costly and environmentally undesirable. In addition, after extensive analysis improper operation practices during compressor startups, steady state operation and gas conditioning have been linked with premature compressor failures, product off spec and safety device failures. The field trial proved the effectiveness of the proposed innovative troubleshooting data analysis techniques in reinstating the gas compression unit in GOSP-A to its recommended design conditions, eliminated compressors and mechanical seal failures and avoided the off-specification products at the lowest operating cost. This innovative technique was based on deep and extensive process data analysis, evaluating operating and design data, reviewing international standards, benchmarking against other facilities, process simulation using Hysys, and finally the actual field trial.
{"title":"Troubleshooting Gas Compression System Using Data Analysis","authors":"A. Al-Aiderous","doi":"10.2118/203367-ms","DOIUrl":"https://doi.org/10.2118/203367-ms","url":null,"abstract":"\u0000 The objective of this paper is to showcase the successful and innovative troubleshooting data analysis techniques in one of the gas compression systems in upstream gas oil separation plants (GOSP-A). The gas compression system using gas compressors, dry gas seal systems and due point controls is used in almost all of upstream operation.\u0000 These proven data analysis techniques were used to tackle major and chronic issues associated with gas compression system operation that lead to excessive flaring, mechanical seal failures, and off-specification products. Dry Gas mechanical seals are an important key element in gas compression and its lifetime represents a concern to the operation personnel. Most gas compression systems have a mechanical seal lifetime of 2 years which in some cases limit production, increase the potential of unnecessary flaring and increase OPEX significantly.\u0000 In this paper, comprehensive data analysis of the potential root causes that aggravate undesired premature mechanical seal failures and off-specification gas products will be discussed along with solutions to minimize expected impact. For example, improper gas conditioning that feeds dry gas mechanical seals increase the risk of premature failures. Additionally, improper product specification in some applications have been found to promote seal failures and incur additional flaring which is both costly and environmentally undesirable. In addition, after extensive analysis improper operation practices during compressor startups, steady state operation and gas conditioning have been linked with premature compressor failures, product off spec and safety device failures.\u0000 The field trial proved the effectiveness of the proposed innovative troubleshooting data analysis techniques in reinstating the gas compression unit in GOSP-A to its recommended design conditions, eliminated compressors and mechanical seal failures and avoided the off-specification products at the lowest operating cost. This innovative technique was based on deep and extensive process data analysis, evaluating operating and design data, reviewing international standards, benchmarking against other facilities, process simulation using Hysys, and finally the actual field trial.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"45 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132857802","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}
H. Kasekar, U. Ghauri, M. Nevin, Raphaele Mel, M. Uijttenhout, J. Alblooshi, E. Draoui
The ADNOC Offshore oilfield located in the Arabian Gulf is being developed utilising various wellhead towers, infield pipelines and a standalone super complex. The field development team devised an updated subsurface plan to achieve production targets beyond the original plan. The incremental oil necessitated assessment of original surface facilities design to identify any bottlenecks and unlock constraints. A set of production forecasts were initially provided as basis for assessment covering various scenarios and range of reservoir uncertainties. To manage these uncertainties, the facilities and subsurface development teams worked in an integrated and iterative way. The production profiles were used to assess and develop understanding of surface facilities such as oil flowline network, water injection supply and network, gas lift networks and the major equipment. The assessment results provided guidelines on the process facilities constraints which were feedback to subsurface team. An optimised subsurface development plan was then generated respecting the facility constraint and leveraging the existing facilities design to utilise ullages. An initial view of investment to produce incremental oil considered installing three new wellhead towers, a new manifold platform and a new water injection platform both linked to the super complex and a new main oil line installation to transfer partially stabilised oil from super complex to oil processing plant. The technical evaluations and the decision analysis resulted in a low-cost solution that was needed to ensure that the field's incremental oil production is economically viable. The integrated approach not only allowed selection of techno-commercial robust solution but also allowed optimisation of investment providing flexibility to accommodate the key project uncertainties. This was achieved by deferring the investment to future by descoping the overall development plan in two separate projects - achieve production plateau and sustain plateau. The interim period between the two projects would provide time to resolve the subsurface uncertainties and an opportunity to revisit future development strategy without committing any investment. In addition, the original UTC was significantly improved. This approach emphasised the importance of having a flexible surface facilities solution in accommodating the developments in the subsurface field development strategy especially in an offshore environment and during the early field production period. This paper presents an approach followed for optimisation of an offshore oilfield development plan under various surface facilities constraints.
{"title":"An Integrated Approach to Optimise an Offshore Field Development Plan","authors":"H. Kasekar, U. Ghauri, M. Nevin, Raphaele Mel, M. Uijttenhout, J. Alblooshi, E. Draoui","doi":"10.2118/202852-ms","DOIUrl":"https://doi.org/10.2118/202852-ms","url":null,"abstract":"\u0000 The ADNOC Offshore oilfield located in the Arabian Gulf is being developed utilising various wellhead towers, infield pipelines and a standalone super complex. The field development team devised an updated subsurface plan to achieve production targets beyond the original plan. The incremental oil necessitated assessment of original surface facilities design to identify any bottlenecks and unlock constraints.\u0000 A set of production forecasts were initially provided as basis for assessment covering various scenarios and range of reservoir uncertainties. To manage these uncertainties, the facilities and subsurface development teams worked in an integrated and iterative way. The production profiles were used to assess and develop understanding of surface facilities such as oil flowline network, water injection supply and network, gas lift networks and the major equipment.\u0000 The assessment results provided guidelines on the process facilities constraints which were feedback to subsurface team. An optimised subsurface development plan was then generated respecting the facility constraint and leveraging the existing facilities design to utilise ullages.\u0000 An initial view of investment to produce incremental oil considered installing three new wellhead towers, a new manifold platform and a new water injection platform both linked to the super complex and a new main oil line installation to transfer partially stabilised oil from super complex to oil processing plant. The technical evaluations and the decision analysis resulted in a low-cost solution that was needed to ensure that the field's incremental oil production is economically viable.\u0000 The integrated approach not only allowed selection of techno-commercial robust solution but also allowed optimisation of investment providing flexibility to accommodate the key project uncertainties. This was achieved by deferring the investment to future by descoping the overall development plan in two separate projects - achieve production plateau and sustain plateau. The interim period between the two projects would provide time to resolve the subsurface uncertainties and an opportunity to revisit future development strategy without committing any investment. In addition, the original UTC was significantly improved. This approach emphasised the importance of having a flexible surface facilities solution in accommodating the developments in the subsurface field development strategy especially in an offshore environment and during the early field production period.\u0000 This paper presents an approach followed for optimisation of an offshore oilfield development plan under various surface facilities constraints.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129164783","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
R. Arias, Khalid S. Al Mohanna, Chengjun Guo, Abdurrezagh Awid
Inflow control device (ICD) completions are becoming a crucial part for many green and brown field developments. However, a typical ICD completion requires a washpipe or inner string to provide fluid circulation, displacement and setting of openhole hydraulic-mechanical packers, which increases operational time, risks and costs. A typical installation process has to follow a series of operational steps to ensure successful deployment of ICD completions. Those necessary operational steps are traditionally achieved using washpipe or an inner string that is run inside the lower completion bottomhole assembly (BHA). This unique and advanced ICD completion design uses proven sliding-sleeve technology that will be run in the closed position to provide fluid circulation, displacement and setting of openhole hydraulic -mechanical packers, and then hydraulically activated to the open position to allow for reservoir-to-well communication. It also incorporates a mechanical-shifting mechanism for future reservoir management and control. The new and advanced ICD completion has undergone a rigorous testing program to ensure the design will deliver those operational requirements and perform appropriately under the worst well operational conditions that are expected during the field life. Following completion of the testing program, the advanced ICD completion was deployed flawlessly in a carbonate reservoir well in the Middle East, representing the first successful deployment globally. The system has functioned as expected with clear surface indication throughout the different operational steps and the final establishment of reservoir-to-well communication which was evidenced by the increase in the well head pressure (WHP). Furthermore, the individual ICD open or closed-sleeve status was verified through production logging (PLT) and coil tubing (CT) shifting operations. The paper describes a comprehensive qualification testing program for the advanced ICD completion design to best serve those well-installation requirements without the need of washpipe. Furthermore, it details the actual well deployment which resulted in improved overall well completion design and operational efficiency.
{"title":"Development and Qualification of a Unique ICD Completion Design to Improve Operational Well Efficiency","authors":"R. Arias, Khalid S. Al Mohanna, Chengjun Guo, Abdurrezagh Awid","doi":"10.2118/202701-ms","DOIUrl":"https://doi.org/10.2118/202701-ms","url":null,"abstract":"\u0000 Inflow control device (ICD) completions are becoming a crucial part for many green and brown field developments. However, a typical ICD completion requires a washpipe or inner string to provide fluid circulation, displacement and setting of openhole hydraulic-mechanical packers, which increases operational time, risks and costs.\u0000 A typical installation process has to follow a series of operational steps to ensure successful deployment of ICD completions. Those necessary operational steps are traditionally achieved using washpipe or an inner string that is run inside the lower completion bottomhole assembly (BHA). This unique and advanced ICD completion design uses proven sliding-sleeve technology that will be run in the closed position to provide fluid circulation, displacement and setting of openhole hydraulic -mechanical packers, and then hydraulically activated to the open position to allow for reservoir-to-well communication. It also incorporates a mechanical-shifting mechanism for future reservoir management and control.\u0000 The new and advanced ICD completion has undergone a rigorous testing program to ensure the design will deliver those operational requirements and perform appropriately under the worst well operational conditions that are expected during the field life. Following completion of the testing program, the advanced ICD completion was deployed flawlessly in a carbonate reservoir well in the Middle East, representing the first successful deployment globally. The system has functioned as expected with clear surface indication throughout the different operational steps and the final establishment of reservoir-to-well communication which was evidenced by the increase in the well head pressure (WHP). Furthermore, the individual ICD open or closed-sleeve status was verified through production logging (PLT) and coil tubing (CT) shifting operations.\u0000 The paper describes a comprehensive qualification testing program for the advanced ICD completion design to best serve those well-installation requirements without the need of washpipe. Furthermore, it details the actual well deployment which resulted in improved overall well completion design and operational efficiency.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-11-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115700303","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}
Samat Ramatullayev, B. Akbayev, D. Tsaplin, Jenis Urazaliev, Andrey Goloborodko
Fractures are common features of many carbonate reservoirs. Given complex flow network that they create, characterization of dynamic behavior of these reservoirs is often complicated and becomes important, especially, if fractures provide primary pathways of fluid flow. In this paper a novel semianalytical simulator was used to understand the pressure behavior of naturally fractured reservoir containing a network of discrete and/or connected finite and infinite-conductivity fractures. In this study an integrated interpretation methodology is applied to analyze well test data acquired in open hole section of exploration well drilled into highly fractured carbonate reservoir of Lower Eocene - Upper Cretaceous sediments on Patardzeuli field of Block XI-B, Republic of Georgia. The main steps consisted of explicitly modeling fractures - both wellbore-intersecting fractures and fractures located away from wellbore - using formation microimager data and calibrating the model to actual well test response using a unique novel mesh-free semi-analytical simulator designed for fractured reservoirs. Study presents the results of well test of one zone performed in highly fractured carbonate reservoir drilled in Patardzeuli field. The pressure-transient response confirmed the complexity of reservoir and dominant contribution to flow regimes from fractures. It is shown in this paper that there are many factors that dominate transient behavior of a well intersected by natural fractures, such as fracture conductivity, length, intensity and distribution, as well as whether fractures intersect the wellbore or not. Moreover, it was demonstrated that presence or absence of damage on wellbore-intersecting fractures in vicinity of wellbore will impact the pressure- transient behavior of reservoir and shape overall productivity of the well. The novelty of the approach is the analysis of the dynamic behavior using a unique semi-analytical pressure transient simulator for fractured reservoirs. The simulator can be used to obtain a response for arbitrarily distributed infinite and/or finite conductivity natural fractures within the reservoir by modeling them explicitly. In this study, it allowed to maximize the value of well tests by assessing the effect of fractures on reservoir dynamic behavior and obtain matrix and fracture parameters where conventional well test interpretation tools would be deemed unviable.
{"title":"The Novel Approach to Pressure Transient Analysis in Highly Fractured Reservoirs: Case Study from Patardzeuli Field, Georgia","authors":"Samat Ramatullayev, B. Akbayev, D. Tsaplin, Jenis Urazaliev, Andrey Goloborodko","doi":"10.2118/202528-ru","DOIUrl":"https://doi.org/10.2118/202528-ru","url":null,"abstract":"\u0000 Fractures are common features of many carbonate reservoirs. Given complex flow network that they create, characterization of dynamic behavior of these reservoirs is often complicated and becomes important, especially, if fractures provide primary pathways of fluid flow. In this paper a novel semianalytical simulator was used to understand the pressure behavior of naturally fractured reservoir containing a network of discrete and/or connected finite and infinite-conductivity fractures.\u0000 In this study an integrated interpretation methodology is applied to analyze well test data acquired in open hole section of exploration well drilled into highly fractured carbonate reservoir of Lower Eocene - Upper Cretaceous sediments on Patardzeuli field of Block XI-B, Republic of Georgia. The main steps consisted of explicitly modeling fractures - both wellbore-intersecting fractures and fractures located away from wellbore - using formation microimager data and calibrating the model to actual well test response using a unique novel mesh-free semi-analytical simulator designed for fractured reservoirs.\u0000 Study presents the results of well test of one zone performed in highly fractured carbonate reservoir drilled in Patardzeuli field. The pressure-transient response confirmed the complexity of reservoir and dominant contribution to flow regimes from fractures.\u0000 It is shown in this paper that there are many factors that dominate transient behavior of a well intersected by natural fractures, such as fracture conductivity, length, intensity and distribution, as well as whether fractures intersect the wellbore or not. Moreover, it was demonstrated that presence or absence of damage on wellbore-intersecting fractures in vicinity of wellbore will impact the pressure- transient behavior of reservoir and shape overall productivity of the well.\u0000 The novelty of the approach is the analysis of the dynamic behavior using a unique semi-analytical pressure transient simulator for fractured reservoirs. The simulator can be used to obtain a response for arbitrarily distributed infinite and/or finite conductivity natural fractures within the reservoir by modeling them explicitly. In this study, it allowed to maximize the value of well tests by assessing the effect of fractures on reservoir dynamic behavior and obtain matrix and fracture parameters where conventional well test interpretation tools would be deemed unviable.","PeriodicalId":357553,"journal":{"name":"Day 2 Tue, November 10, 2020","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122250799","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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