I. Yamalov, V. Ovcharov, A. Akimov, E. Gadelshin, A. Aslanyan, V. Krichevsky, D. Gulyaev, R. Farakhova
The massive industry digitalization creates huge data banks which require dedicated data processing techniques. A good example of such a massive data bank is the long-term pressure records of Permanent Downhole Gauges (PDG) which became very popular in the last 20 years and currently cover thousands of wells in Company RN. Many data processing techniques have been applied to interpret the PDG data, both single-well (IPR, RTA[1]) and multi-well (CRM [2] - [5] and various statistical correlation models). The ability of any methodology to predict the pressure response to rate variations and/or rate response to pressure variations can be easily tested via numerical modelling of synthetic fields or via comparison with the actual field production history. This paper presents a Multi-well Retrospective Testing (MRT, see Appendix A and [6] - [9]) methodology of PDG data analysis which is based on the Multi-well Deconvolution (MDCV, see Appendix B and [10] - [20]) and the results of its blind testing against synthetic and real fields. The key idea of the MDCV is to find a reference transient pressure response (called UTR) to the unit-rate production in the same well (specifically called DTR) or offset wells (specifically called CTR) and then use convolution to predict pressure response to arbitrary rate history with an account of cross-well interference. The MRT analysis is using the reconstructed UTRs (DTRs and CTRs) to predict the pressure/rates and reconstruct the past formation pressure history, productivity index history, cross-well interference history and reservoir properties like potential and dynamic drainage volumes and transmissibility. The results of the MRT blind testing have concluded that MRT could be recommended as an efficient tool to estimate the current and predict the future formation pressure without production deferment caused by temporary shut-down for pressure build up. It showed the ability to accurately reconstruct the past formation pressure history and productivity index. It also reconstructs the well-by-well cross-well interference and reservoir properties around and between the wells. The blind-test also revealed limitations of the method and the way to diagnose the trust of the MRT predictions. Engineers are now considering using MRT in Company RN as a part of the selection/justification package for the new wells drilling, conversions, workovers, production optimization and selection of surveillance candidates.
{"title":"Systematic Approach in Testing Field Data Analysis Techniques with an Example of Multiwell Retrospective Testing","authors":"I. Yamalov, V. Ovcharov, A. Akimov, E. Gadelshin, A. Aslanyan, V. Krichevsky, D. Gulyaev, R. Farakhova","doi":"10.4043/30101-ms","DOIUrl":"https://doi.org/10.4043/30101-ms","url":null,"abstract":"\u0000 The massive industry digitalization creates huge data banks which require dedicated data processing techniques.\u0000 A good example of such a massive data bank is the long-term pressure records of Permanent Downhole Gauges (PDG) which became very popular in the last 20 years and currently cover thousands of wells in Company RN.\u0000 Many data processing techniques have been applied to interpret the PDG data, both single-well (IPR, RTA[1]) and multi-well (CRM [2] - [5] and various statistical correlation models).\u0000 The ability of any methodology to predict the pressure response to rate variations and/or rate response to pressure variations can be easily tested via numerical modelling of synthetic fields or via comparison with the actual field production history.\u0000 This paper presents a Multi-well Retrospective Testing (MRT, see Appendix A and [6] - [9]) methodology of PDG data analysis which is based on the Multi-well Deconvolution (MDCV, see Appendix B and [10] - [20]) and the results of its blind testing against synthetic and real fields.\u0000 The key idea of the MDCV is to find a reference transient pressure response (called UTR) to the unit-rate production in the same well (specifically called DTR) or offset wells (specifically called CTR) and then use convolution to predict pressure response to arbitrary rate history with an account of cross-well interference.\u0000 The MRT analysis is using the reconstructed UTRs (DTRs and CTRs) to predict the pressure/rates and reconstruct the past formation pressure history, productivity index history, cross-well interference history and reservoir properties like potential and dynamic drainage volumes and transmissibility.\u0000 The results of the MRT blind testing have concluded that MRT could be recommended as an efficient tool to estimate the current and predict the future formation pressure without production deferment caused by temporary shut-down for pressure build up. It showed the ability to accurately reconstruct the past formation pressure history and productivity index. It also reconstructs the well-by-well cross-well interference and reservoir properties around and between the wells.\u0000 The blind-test also revealed limitations of the method and the way to diagnose the trust of the MRT predictions.\u0000 Engineers are now considering using MRT in Company RN as a part of the selection/justification package for the new wells drilling, conversions, workovers, production optimization and selection of surveillance candidates.","PeriodicalId":358085,"journal":{"name":"Day 4 Thu, November 05, 2020","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131586317","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 paper presents a comprehensive laboratory evaluation of Schizophyllan as an EOR polymer candidate for a selected peninsular Malaysia field. The polymer was chosen due to its well-known structure and properties. Schizophyllan, which originally produced from Schizophyllum commune was evaluated for its performance under controlled laboratory condition and the results are discussed accordingly. Rheology analysis at 96°C, showed that, at low concentration of 250ppm, Schizophyllan can achieve 11 cP which is about 90% more than live crude oil viscosity. Thermal Stability of this polymer was also excellent for the entire 3 months of exposure at reservoir temperature, whereby only 2.8% of viscosity degradation recorded with a very clear solution observed representing the heat and hardness resistance of the polymer. Injectivity test using actual native core indicated that, there was no plugging tendency or injectivity problem observed from the coreflooding test based on its low RRF value of 1.5. The resistance factor value of 9.93 indicates that this polymer is effective in viscosifying the water and injectable into the core. Dynamic adsorption study also showed that only 0.09mg/L of polymer was found adsorbed to the actual native core, despite the presence of clay in the core. Hence, from all the analysis, it was found that Schizophyllan meets the technical requirement to be applied as an EOR polymer
{"title":"Schizophyllan as Potential Environmental Friendly EOR Polymer for A Selected Malaysian Field","authors":"Norhidayah Ahmad Wazir, A. A. A. Manap","doi":"10.4043/30224-ms","DOIUrl":"https://doi.org/10.4043/30224-ms","url":null,"abstract":"\u0000 This paper presents a comprehensive laboratory evaluation of Schizophyllan as an EOR polymer candidate for a selected peninsular Malaysia field. The polymer was chosen due to its well-known structure and properties. Schizophyllan, which originally produced from Schizophyllum commune was evaluated for its performance under controlled laboratory condition and the results are discussed accordingly. Rheology analysis at 96°C, showed that, at low concentration of 250ppm, Schizophyllan can achieve 11 cP which is about 90% more than live crude oil viscosity. Thermal Stability of this polymer was also excellent for the entire 3 months of exposure at reservoir temperature, whereby only 2.8% of viscosity degradation recorded with a very clear solution observed representing the heat and hardness resistance of the polymer. Injectivity test using actual native core indicated that, there was no plugging tendency or injectivity problem observed from the coreflooding test based on its low RRF value of 1.5. The resistance factor value of 9.93 indicates that this polymer is effective in viscosifying the water and injectable into the core. Dynamic adsorption study also showed that only 0.09mg/L of polymer was found adsorbed to the actual native core, despite the presence of clay in the core. Hence, from all the analysis, it was found that Schizophyllan meets the technical requirement to be applied as an EOR polymer","PeriodicalId":358085,"journal":{"name":"Day 4 Thu, November 05, 2020","volume":"148 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116382523","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}
Pipelines are critical for transportation of oil and gas. A Steel Strip Reinforced Thermoplastic Pipe (SSRTP) is applied in the offshore environment because of its superior mechanical performance. Due to the complex subsea conditions, SSRTP is subject to severe loading and may be damaged during its design life. The failure modes of SSRTP, related to four principle loading cases, are investigated in the FE models. The preliminary results will reveal the mechanical behavior of the critical layer of SSRTP prior to damage. An optical fiber sensor is then introduced within the SSRTP as a novel system to monitor the strain of the critical layer.
{"title":"Structural Health Monitoring of Unbonded Flexible Pipe Using Optical Fiber Sensor","authors":"Wen-Lung Kuang, P. P. Ong, S. Quek, K. Kuang","doi":"10.4043/30116-ms","DOIUrl":"https://doi.org/10.4043/30116-ms","url":null,"abstract":"\u0000 Pipelines are critical for transportation of oil and gas. A Steel Strip Reinforced Thermoplastic Pipe (SSRTP) is applied in the offshore environment because of its superior mechanical performance. Due to the complex subsea conditions, SSRTP is subject to severe loading and may be damaged during its design life. The failure modes of SSRTP, related to four principle loading cases, are investigated in the FE models. The preliminary results will reveal the mechanical behavior of the critical layer of SSRTP prior to damage. An optical fiber sensor is then introduced within the SSRTP as a novel system to monitor the strain of the critical layer.","PeriodicalId":358085,"journal":{"name":"Day 4 Thu, November 05, 2020","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130166600","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. Jaafar, A. T. Obaidellah, K. A. Karim, Hayati Hussien, M. N. B. Ali, M. Yunus
Operators around the world are reviewing their aging assets, and are coming to clench with the reality that some offshore fields are no longer economically viable. The North Sea and the Gulf of Mexico have seen numbers of decommissioning activities. In other regions, decommissioning activities had started to emerge, now and in the coming years. Decommissioning, an easy-look-but-massive-task come with unique challenges and cost ranging in the billions. Delivering an effective decommissioning especially when dealing with deep-water operations are paramount as to secure the economic value from the assets. Health, Safety and Environmental (HSE) concerns are always vital in any decommissioning process. The target is to effectively reduce the long term risks to other benefactors of the sea while the associated short term risks to those responsible for decommissioning operations are minimized. A major part of any decommissioning project is the decommissioning of subsea pipelines including the flowlines and risers. Referring to a field case example from one of PETRONAS's deepwater field decommissioning project in Atlantic Ocean, a numbers of techniques had been considered for decommissioning of subsea pipeline system which sited in 700m to 960m water depth, ranging from preservation for potential future use, leaving in-situ or full recovery. Noted that each subsea pipeline decommissioning technique should be considered on its own merit, thus the assessment of each decommissioning technique had been based on many parameters, amongst others, size of pipeline, type of pipeline (e.g. single pipe, pipe-in-pipe, flexible), type of fluid in the pipeline, operational environment (location), production history, Inspection, Repair and Maintenance (IRM) records, HSE considerations, connection to other facilities, technical feasibility (including potential use of advanced technologies), regulatory authorities requirements and socio-economic considerations. This paper covers only at specific of PETRONAS deepwater subsea flowlines and risers decommissioning experiences. It outlines the activities done starting from desk top activities (e.g. planning and concept) up to operational activities (e.g. pigging, flushing, cleaning, disconnection, retrieval or leaving in-situ). Different considered scenarios are discussed and potential advantages and disadvantages of each scenario are presented.
{"title":"Deepwater Flowlines and Risers Decommissioning","authors":"A. Jaafar, A. T. Obaidellah, K. A. Karim, Hayati Hussien, M. N. B. Ali, M. Yunus","doi":"10.4043/30397-ms","DOIUrl":"https://doi.org/10.4043/30397-ms","url":null,"abstract":"\u0000 Operators around the world are reviewing their aging assets, and are coming to clench with the reality that some offshore fields are no longer economically viable. The North Sea and the Gulf of Mexico have seen numbers of decommissioning activities. In other regions, decommissioning activities had started to emerge, now and in the coming years. Decommissioning, an easy-look-but-massive-task come with unique challenges and cost ranging in the billions. Delivering an effective decommissioning especially when dealing with deep-water operations are paramount as to secure the economic value from the assets. Health, Safety and Environmental (HSE) concerns are always vital in any decommissioning process. The target is to effectively reduce the long term risks to other benefactors of the sea while the associated short term risks to those responsible for decommissioning operations are minimized. A major part of any decommissioning project is the decommissioning of subsea pipelines including the flowlines and risers.\u0000 Referring to a field case example from one of PETRONAS's deepwater field decommissioning project in Atlantic Ocean, a numbers of techniques had been considered for decommissioning of subsea pipeline system which sited in 700m to 960m water depth, ranging from preservation for potential future use, leaving in-situ or full recovery. Noted that each subsea pipeline decommissioning technique should be considered on its own merit, thus the assessment of each decommissioning technique had been based on many parameters, amongst others, size of pipeline, type of pipeline (e.g. single pipe, pipe-in-pipe, flexible), type of fluid in the pipeline, operational environment (location), production history, Inspection, Repair and Maintenance (IRM) records, HSE considerations, connection to other facilities, technical feasibility (including potential use of advanced technologies), regulatory authorities requirements and socio-economic considerations.\u0000 This paper covers only at specific of PETRONAS deepwater subsea flowlines and risers decommissioning experiences. It outlines the activities done starting from desk top activities (e.g. planning and concept) up to operational activities (e.g. pigging, flushing, cleaning, disconnection, retrieval or leaving in-situ). Different considered scenarios are discussed and potential advantages and disadvantages of each scenario are presented.","PeriodicalId":358085,"journal":{"name":"Day 4 Thu, November 05, 2020","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134426240","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. Tibbles, Kesavan Govinathan, I. Mickelburgh, Samyak Jain, Philip Wassouf
The sand control completion is the last step in the well construction. It is the step that turns the well from an expense to a revenue generating asset. While every sand control completion is designed for success, things don't always go to plan during the installation, and the technical and commercial results are sometimes less than perfect. Failures can range from minor issues that can be easily remedied to catastrophic events that put the entire well, and investment, at risk. Regardless of severity, it is critical that all failures are analyzed to determine the root cause, prevent them from being repeated and protect asset value. The success of a sand control installation should not be assumed and can only be confirmed with a thorough review of all available job data. This paper introduces several case studies of failures that occurred during sand control installations and details the investigative process and techniques used to identify the root causes. Examples include events such as screen/wash-pipe damage, bridging, hole collapse, and packer seal failure. This analysis provides key insights into downhole events and mechanisms that can be used to minimize risk and improve future completions.
{"title":"Understanding Sand Control Installation Failures","authors":"R. Tibbles, Kesavan Govinathan, I. Mickelburgh, Samyak Jain, Philip Wassouf","doi":"10.2118/199251-ms","DOIUrl":"https://doi.org/10.2118/199251-ms","url":null,"abstract":"\u0000 The sand control completion is the last step in the well construction. It is the step that turns the well from an expense to a revenue generating asset. While every sand control completion is designed for success, things don't always go to plan during the installation, and the technical and commercial results are sometimes less than perfect. Failures can range from minor issues that can be easily remedied to catastrophic events that put the entire well, and investment, at risk. Regardless of severity, it is critical that all failures are analyzed to determine the root cause, prevent them from being repeated and protect asset value. The success of a sand control installation should not be assumed and can only be confirmed with a thorough review of all available job data.\u0000 This paper introduces several case studies of failures that occurred during sand control installations and details the investigative process and techniques used to identify the root causes. Examples include events such as screen/wash-pipe damage, bridging, hole collapse, and packer seal failure. This analysis provides key insights into downhole events and mechanisms that can be used to minimize risk and improve future completions.","PeriodicalId":358085,"journal":{"name":"Day 4 Thu, November 05, 2020","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122194970","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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