Zheng Sun, Keliu Wu, Juntai Shi, Jin Fu, Chang-fei Shao, Yu Zhou, Chengyuan Liu, Yanran Jia, J. Fang, M. Lv
A great deal of attention has been attracted to the exploitation as well as the development of unconventional gas reservoirs, which expect to act as an essential role in counterpoising the daily increasing energy demand around the world. In this research, with the intent of contributing to the successful development of coalbed methane (CBM) reservoirs, which is an indispensable member of the family of unconventional gas reservoirs, a novel production prediction model is proposed for fractured vertical CBM wells. The main difference of the research compared with previous excellent documents is taking the effect of pressure propagation behavior on production performance of CBM wells into account. In general, CBM reservoirs possess the low-permeability (<1 mD) physical property, which results in the slow pressure propagation speed during the whole production life. More importantly, because of the unique gas desorption effect inside coal matrix system, more and more adsorption gas will enter into coal cleat system with the production proceed, which will accumulate the formation energy and further mitigate the pressure propagation speed. As a result, it is a relatively time-lengthy period for the pressure propagation process with regard to CBM reservoirs, which currently has not been detailed and comprehensively analyzed. Additionally, it should be noted that the formation pressure is a key sensitive parameter affecting production performance of CBM wells, resulting from the fact that gas production rate takes place only when formation pressure is lower than critical desorption pressure. In this view, the pressure propagation behavior shows a close relationship with production performance of CBM wells, which however fails to receive due attention up to date. In these regards, research content in this paper attempts to shed light on the effect of pressure propagation behavior on production performance of CBM wells from both theoretical and application scopes. With the capacity of capturing the pressure propagation behavior, a novel production prediction model is proposed for fractured vertical CBM wells, the reliability and accuracy of which has been well verified by numerical simulator. Also, the pressure propagation details during production process can be characterized by the proposed model, which is supposed to be highlighted as the main novel point when comparing with previous models. The proposed model is able to generate sensible production performance with less input parameters and calculation time than that of a full-calibrated numerical simulator. Furthermore, details of formation pressure variation regularity are clearly presented by the proposed model, which provides a completely new pathway to evaluate and optimize production performance of fractured vertical CBM wells.
{"title":"A Practical Model for Production Forecast of Fractured Vertical Well in Coalbed Methane Reservoirs: Dynamic-Drainage-Area Concept","authors":"Zheng Sun, Keliu Wu, Juntai Shi, Jin Fu, Chang-fei Shao, Yu Zhou, Chengyuan Liu, Yanran Jia, J. Fang, M. Lv","doi":"10.4043/29877-ms","DOIUrl":"https://doi.org/10.4043/29877-ms","url":null,"abstract":"\u0000 A great deal of attention has been attracted to the exploitation as well as the development of unconventional gas reservoirs, which expect to act as an essential role in counterpoising the daily increasing energy demand around the world. In this research, with the intent of contributing to the successful development of coalbed methane (CBM) reservoirs, which is an indispensable member of the family of unconventional gas reservoirs, a novel production prediction model is proposed for fractured vertical CBM wells. The main difference of the research compared with previous excellent documents is taking the effect of pressure propagation behavior on production performance of CBM wells into account. In general, CBM reservoirs possess the low-permeability (<1 mD) physical property, which results in the slow pressure propagation speed during the whole production life. More importantly, because of the unique gas desorption effect inside coal matrix system, more and more adsorption gas will enter into coal cleat system with the production proceed, which will accumulate the formation energy and further mitigate the pressure propagation speed. As a result, it is a relatively time-lengthy period for the pressure propagation process with regard to CBM reservoirs, which currently has not been detailed and comprehensively analyzed. Additionally, it should be noted that the formation pressure is a key sensitive parameter affecting production performance of CBM wells, resulting from the fact that gas production rate takes place only when formation pressure is lower than critical desorption pressure. In this view, the pressure propagation behavior shows a close relationship with production performance of CBM wells, which however fails to receive due attention up to date. In these regards, research content in this paper attempts to shed light on the effect of pressure propagation behavior on production performance of CBM wells from both theoretical and application scopes. With the capacity of capturing the pressure propagation behavior, a novel production prediction model is proposed for fractured vertical CBM wells, the reliability and accuracy of which has been well verified by numerical simulator. Also, the pressure propagation details during production process can be characterized by the proposed model, which is supposed to be highlighted as the main novel point when comparing with previous models. The proposed model is able to generate sensible production performance with less input parameters and calculation time than that of a full-calibrated numerical simulator. Furthermore, details of formation pressure variation regularity are clearly presented by the proposed model, which provides a completely new pathway to evaluate and optimize production performance of fractured vertical CBM wells.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128086995","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}
S. Benelkadi, Eduardo Bianco, P. Burton, Marcelo Dourado Motta
Drilling waste generated during development of oil and gas offshore and onshore fields are required to be disposed of in a responsible and environmentally friendly manner. The remoteness of such environments, coupled with the ever-tightening environmental regulations and then green operation initiatives of operators, can create significant economical, logistical and regulatory challenges. The subsurface drilling cuttings reinjection becomes the preferred option allowing oil and gas operators to achieve zero discharge which can meet the most stringent environmental standards. To prevent all possible injection issues that were experienced earlier in the industry globally (early 1990's), a novel "design, execute, evaluate approach was introduced, this enables us to deliver reliable, single sourced start to finish solutions Subsurface drilling waste injection has been and continues to be used on several offshore projects where many millions of barrels of waste have been injected in a single well. This has been achieved through the engineering approach "design, execute, evaluate". The design study assesses the subsurface strata and identifies suitable injection zones, with a focus on waste containment assurance. The execution and evaluation phase begins with an initial injectivity test to calibrate all the reinjection modelling completed so far, we then implement real time injections surveillance including advanced pressure analysis as a risk control tool. The key focus is to analyze, identify, and recommend necessary adjustments during injections to prevent injection failure. The studied cases have been operated successfully since their start to date. No injectivity issues have been experienced during drilling waste fluids injections. Several on-time interventions have been made to proactively prevent the well becoming plugged and maintaining surface injection pressures within normal ranges. Recent advances of Real-time data streaming have made big step change improvement in the data delivery process, monitoring pressure analysis. It creates a direct link between the wellsite and worldwide multidisciplinary technical expertise and provides visualization capability at anytime and anywhere to all personnel involved in the project. This step change in monitoring drilling cuttings reinjection operations provides truly "Acquisition to Answer" integrated solution, mitigates the injection risks and enhances the intrinsic value of drilling cuttings reinjection on offshore development projects. This paper shares the experience and the success of subsurface drilling cuttings reinjection where wastes are injected for final and responsible disposal. The offshore field cases are presented to illustrate the value of the recent technological advances along with best practice guidelines and recommendations for safe and economical disposal of drilling waste fluids to achieve true zero discharge results.
{"title":"Subsurface Drilling Waste Injection: Challenges, Recent Advances and Cases Studies","authors":"S. Benelkadi, Eduardo Bianco, P. Burton, Marcelo Dourado Motta","doi":"10.4043/29920-ms","DOIUrl":"https://doi.org/10.4043/29920-ms","url":null,"abstract":"\u0000 Drilling waste generated during development of oil and gas offshore and onshore fields are required to be disposed of in a responsible and environmentally friendly manner. The remoteness of such environments, coupled with the ever-tightening environmental regulations and then green operation initiatives of operators, can create significant economical, logistical and regulatory challenges. The subsurface drilling cuttings reinjection becomes the preferred option allowing oil and gas operators to achieve zero discharge which can meet the most stringent environmental standards.\u0000 To prevent all possible injection issues that were experienced earlier in the industry globally (early 1990's), a novel \"design, execute, evaluate approach was introduced, this enables us to deliver reliable, single sourced start to finish solutions\u0000 Subsurface drilling waste injection has been and continues to be used on several offshore projects where many millions of barrels of waste have been injected in a single well. This has been achieved through the engineering approach \"design, execute, evaluate\". The design study assesses the subsurface strata and identifies suitable injection zones, with a focus on waste containment assurance. The execution and evaluation phase begins with an initial injectivity test to calibrate all the reinjection modelling completed so far, we then implement real time injections surveillance including advanced pressure analysis as a risk control tool. The key focus is to analyze, identify, and recommend necessary adjustments during injections to prevent injection failure.\u0000 The studied cases have been operated successfully since their start to date. No injectivity issues have been experienced during drilling waste fluids injections. Several on-time interventions have been made to proactively prevent the well becoming plugged and maintaining surface injection pressures within normal ranges.\u0000 Recent advances of Real-time data streaming have made big step change improvement in the data delivery process, monitoring pressure analysis. It creates a direct link between the wellsite and worldwide multidisciplinary technical expertise and provides visualization capability at anytime and anywhere to all personnel involved in the project.\u0000 This step change in monitoring drilling cuttings reinjection operations provides truly \"Acquisition to Answer\" integrated solution, mitigates the injection risks and enhances the intrinsic value of drilling cuttings reinjection on offshore development projects.\u0000 This paper shares the experience and the success of subsurface drilling cuttings reinjection where wastes are injected for final and responsible disposal. The offshore field cases are presented to illustrate the value of the recent technological advances along with best practice guidelines and recommendations for safe and economical disposal of drilling waste fluids to achieve true zero discharge results.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133425499","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}
Rômulo Alves Loretti, Vitor Felipe Pereira Da Costa, D. Memoria, A. Barbosa, Helton Luiz Santana Oliveira, Issac Rafael Wegner, C. A. C. Zank
Incorporating data science and business intelligence (BI) techniques as a strategy and tool for improving and evolving process safety for the oil and gas industry is a no-return method that should provide extraordinary gains. The technology is a powerful and necessary partner for the oil industry to overcome the challenges of new frontiers for oil exploration and production. Additionally, this applies to the health, safety, and environmental segment of business because more challenging scenarios imply greater potential risks; therefore, access to information within the appropriate time, clearly, and consistently allows the longevity of business. Digital transformation, helped current activities supported by weak instruments (i.e., spreadsheets, e-mails, etc.) to migrate to a database structure that facilitated the understanding of their real situation within the appropriate time—at macro and micro levels—allowing adequate support for decision-making. BI tools aided by data science techniques facilitate decision-making, often extracting productive information from content-rich texts. The combination of data science techniques with BI tools enables a full-blown experience for business analysts through new insights, background connections not yet discussed, more professional visualizations, and telling the same or a new story using more complete, and often complex, innovative questions and answers. Answering essential questions for process safety in the oil and gas industry when analyzing environmental accidents, atmospheric dispersions, emissions, leaks, and spills in a structured method (presenting graphically within the context of rigs), multiple views of the problem allow improved management of efforts, which reduces the number of cases. The same concept can be expanded to questions related to injuries, machinery and/or equipment damage, performance, etc.
{"title":"Data Science and Business Intelligence Techniques for Learning from Environmental Accident Analysis for Offshore Oil Fields","authors":"Rômulo Alves Loretti, Vitor Felipe Pereira Da Costa, D. Memoria, A. Barbosa, Helton Luiz Santana Oliveira, Issac Rafael Wegner, C. A. C. Zank","doi":"10.4043/29725-ms","DOIUrl":"https://doi.org/10.4043/29725-ms","url":null,"abstract":"\u0000 Incorporating data science and business intelligence (BI) techniques as a strategy and tool for improving and evolving process safety for the oil and gas industry is a no-return method that should provide extraordinary gains. The technology is a powerful and necessary partner for the oil industry to overcome the challenges of new frontiers for oil exploration and production. Additionally, this applies to the health, safety, and environmental segment of business because more challenging scenarios imply greater potential risks; therefore, access to information within the appropriate time, clearly, and consistently allows the longevity of business. Digital transformation, helped current activities supported by weak instruments (i.e., spreadsheets, e-mails, etc.) to migrate to a database structure that facilitated the understanding of their real situation within the appropriate time—at macro and micro levels—allowing adequate support for decision-making.\u0000 BI tools aided by data science techniques facilitate decision-making, often extracting productive information from content-rich texts. The combination of data science techniques with BI tools enables a full-blown experience for business analysts through new insights, background connections not yet discussed, more professional visualizations, and telling the same or a new story using more complete, and often complex, innovative questions and answers. Answering essential questions for process safety in the oil and gas industry when analyzing environmental accidents, atmospheric dispersions, emissions, leaks, and spills in a structured method (presenting graphically within the context of rigs), multiple views of the problem allow improved management of efforts, which reduces the number of cases. The same concept can be expanded to questions related to injuries, machinery and/or equipment damage, performance, etc.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123246072","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}
D. K. Agrawal, Radhika Suresh, Qusai A. Darugar, V. Khabashesku
Surfactant losses due to adsorption in the hydrocarbon reservoir is a major concern in surfactant based chemical enhance oil recovery (chemical EOR) methods because it results in the loss of optimum concentration required for adequately reducing oil-water interfacial tension (IFT). Much higher concertation of surfactant than the optimally designed concentration in the EOR formulation has to be injected in order to account for the surfactant losses in the reservoir which often makes the whole EOR process uneconomical. Although extensive research has been performed with surfactants and nanoparticles in porous media as separate entities, but not much work has been done to understand their combined effects on oil mobilization and adsorption in clay containing reservoirs. The objective of this work is to study uniquely surface modified silica nanoparticles and understand their influence in reducing surfactant adsorption in clay containing reservoirs and develop appropriate injection strategies. Thermally stable negatively charged silica nanoparticles were developed via surface modification. Static and dynamic adsorption studies were conducted at 80 °C in seawater brine. Static adsorption studies were conducted in the glass vials without any agitation or movement of the fluids. Dynamic adsorption experiments were conducted on the sandpack flow setup. Total of 190 grams of 20/40 mesh gravel pack sand and 10 grams of Kaolinite clay were used to make 9 inches tall column. Two injection strategies for nanoparticles treatment was evaluated – Single Step Injection and Two Steps Injection. In single step, nanoparticles and surfactant were mixed to form single injection fluid, while in the case of two steps injection, porous medium was pre-treated with the nanoparticles before surfactant injection. Thermogravimetric weight loss analysis was used to measure surfactant concentration in the eluting samples. Particle count analysis using dynamic light scattering technique was used to measure the silica nanoparticles concentration. Negatively charged silica nanoparticles were found to adsorb at a much lower rate than surfactants. Static adsorption tests showed that Kaolinite clay containing samples adsorbed significantly more surfactant compared to the samples without Kaolinite clay and the surfactant adsorption was much lower in the presence of negatively charged nanoparticles. Dynamic adsorption results showed nanoparticles injection significantly reduced the surfactant adsorption in the column and the two steps injection was several times more effective in reducing the surfactant adsorption compared to the single step injection. This work evaluated two injection strategies for the nanoparticles treatment in clay containing reservoir. Static and dynamic adsorption testing results demonstrated significant reduction in surfactant adsorption at 80 °C temperature in seawater. The findings from this work are helpful in designing more efficient surfactant EOR meth
{"title":"Nanoparticles Treatment for Reducing Surfactant Adsorption in Clay Containing Reservoirs","authors":"D. K. Agrawal, Radhika Suresh, Qusai A. Darugar, V. Khabashesku","doi":"10.4043/29931-ms","DOIUrl":"https://doi.org/10.4043/29931-ms","url":null,"abstract":"\u0000 Surfactant losses due to adsorption in the hydrocarbon reservoir is a major concern in surfactant based chemical enhance oil recovery (chemical EOR) methods because it results in the loss of optimum concentration required for adequately reducing oil-water interfacial tension (IFT). Much higher concertation of surfactant than the optimally designed concentration in the EOR formulation has to be injected in order to account for the surfactant losses in the reservoir which often makes the whole EOR process uneconomical. Although extensive research has been performed with surfactants and nanoparticles in porous media as separate entities, but not much work has been done to understand their combined effects on oil mobilization and adsorption in clay containing reservoirs. The objective of this work is to study uniquely surface modified silica nanoparticles and understand their influence in reducing surfactant adsorption in clay containing reservoirs and develop appropriate injection strategies.\u0000 Thermally stable negatively charged silica nanoparticles were developed via surface modification. Static and dynamic adsorption studies were conducted at 80 °C in seawater brine. Static adsorption studies were conducted in the glass vials without any agitation or movement of the fluids. Dynamic adsorption experiments were conducted on the sandpack flow setup. Total of 190 grams of 20/40 mesh gravel pack sand and 10 grams of Kaolinite clay were used to make 9 inches tall column. Two injection strategies for nanoparticles treatment was evaluated – Single Step Injection and Two Steps Injection. In single step, nanoparticles and surfactant were mixed to form single injection fluid, while in the case of two steps injection, porous medium was pre-treated with the nanoparticles before surfactant injection. Thermogravimetric weight loss analysis was used to measure surfactant concentration in the eluting samples. Particle count analysis using dynamic light scattering technique was used to measure the silica nanoparticles concentration.\u0000 Negatively charged silica nanoparticles were found to adsorb at a much lower rate than surfactants. Static adsorption tests showed that Kaolinite clay containing samples adsorbed significantly more surfactant compared to the samples without Kaolinite clay and the surfactant adsorption was much lower in the presence of negatively charged nanoparticles. Dynamic adsorption results showed nanoparticles injection significantly reduced the surfactant adsorption in the column and the two steps injection was several times more effective in reducing the surfactant adsorption compared to the single step injection.\u0000 This work evaluated two injection strategies for the nanoparticles treatment in clay containing reservoir. Static and dynamic adsorption testing results demonstrated significant reduction in surfactant adsorption at 80 °C temperature in seawater. The findings from this work are helpful in designing more efficient surfactant EOR meth","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115925337","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}
Lucas Lima Mota de, Diogo Santos Baleeiro, Breno Peixoto Cortez
In a global context of an irreversible trend of decarbonization of the economy, natural gas plays a prominent role in the global commitment to reduce carbon indices, and its exploration will contribute to the transition of the world's electric and energy matrix. Brazil has enormous potential when it comes to natural gas, particularly in the pre-salt province, which is considered to be the largest oil discovery in the Southern Hemisphere in the last thirty years. If on the one hand, the pre-salt has a great potential for natural gas production, on the other, there are enormous technological and logistical challenges to enable the commercial use and monetization of this gas produced. In this context, the present work proposes to present a contribution to the study of the use of Gas to Wire (GTW) as a technological alternative for the use and monetization of the natural gas from pre-salt province. For that, a review of the specialized literature, including specific periodic data in O&G, and an economic evaluation of the use of GTW in the pre-salt province were carried out, comparing it with the concept of a GTW plant in an onshore environment. In an optimistic production scenario, and even with the expected expansion of the pre-salt gas flow line routes, the difference between the natural gas produced and the injected, burnt gas, used in the offshore site and outflow facilities, will be positive at 15 MMm3/day and will cause operators to seek alternatives for valuation of this resource, since if commercial use is not viable, operators will simply have to paralyze the development and production of their fields, whereas pre-salt natural gas is generally associated with oil. The GTW emerges an alternative technology for the utilization and monetization of natural gas across the inflexibility of gas production not associated with the pre-salt fields. The economic costs for deploying an offshore GTW system and the level of energy cost aiming the use of pre-salt natural gas were competitive accounting for 84% to 91% of the costs of generating a GTW plant in an onshore environment. The case study demonstrates that the concept of GTW can be economically viable, with limitations, such as technological alternative for the utilization and monetization of natural gas across the inflexibility of gas production not associated with the pre-salt fields.
{"title":"Gas to Wire as an Alternative to Natural Gas Monetization of the Pre-Salt Province in Brazil","authors":"Lucas Lima Mota de, Diogo Santos Baleeiro, Breno Peixoto Cortez","doi":"10.4043/29852-ms","DOIUrl":"https://doi.org/10.4043/29852-ms","url":null,"abstract":"\u0000 In a global context of an irreversible trend of decarbonization of the economy, natural gas plays a prominent role in the global commitment to reduce carbon indices, and its exploration will contribute to the transition of the world's electric and energy matrix. Brazil has enormous potential when it comes to natural gas, particularly in the pre-salt province, which is considered to be the largest oil discovery in the Southern Hemisphere in the last thirty years. If on the one hand, the pre-salt has a great potential for natural gas production, on the other, there are enormous technological and logistical challenges to enable the commercial use and monetization of this gas produced. In this context, the present work proposes to present a contribution to the study of the use of Gas to Wire (GTW) as a technological alternative for the use and monetization of the natural gas from pre-salt province. For that, a review of the specialized literature, including specific periodic data in O&G, and an economic evaluation of the use of GTW in the pre-salt province were carried out, comparing it with the concept of a GTW plant in an onshore environment. In an optimistic production scenario, and even with the expected expansion of the pre-salt gas flow line routes, the difference between the natural gas produced and the injected, burnt gas, used in the offshore site and outflow facilities, will be positive at 15 MMm3/day and will cause operators to seek alternatives for valuation of this resource, since if commercial use is not viable, operators will simply have to paralyze the development and production of their fields, whereas pre-salt natural gas is generally associated with oil. The GTW emerges an alternative technology for the utilization and monetization of natural gas across the inflexibility of gas production not associated with the pre-salt fields. The economic costs for deploying an offshore GTW system and the level of energy cost aiming the use of pre-salt natural gas were competitive accounting for 84% to 91% of the costs of generating a GTW plant in an onshore environment. The case study demonstrates that the concept of GTW can be economically viable, with limitations, such as technological alternative for the utilization and monetization of natural gas across the inflexibility of gas production not associated with the pre-salt fields.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116475240","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}
C. Guimaraes, E. Delgado, L. Galvão, Adriano Frotte, Manoel Gouveia, Carlos Alberto Teles Borges
The systematic approach adopted by a service company and a Brazilian National Oil Company (NOC) to achieve the goal of safely abandoning wells with different completion types using light workover vessels is discussed. Having determined the abandonment methodology, the service company personnel developed processes and procedures to reach the objective. These include advances in coiled tubing (CT) rigup procedures and using a real-time telemetry system. This approach facilitated the timely and cost effective abandonment of more than 15 wells since 2017 in a safe and environmentally acceptable manner.
{"title":"Successful Offshore Coiled-Tubing Permanent Well-Abandonment Operation Uses Downhole Real-Time Parameters to Set Inflatable Packers with Surgical Precision in Cost-Effective Manner","authors":"C. Guimaraes, E. Delgado, L. Galvão, Adriano Frotte, Manoel Gouveia, Carlos Alberto Teles Borges","doi":"10.4043/29839-ms","DOIUrl":"https://doi.org/10.4043/29839-ms","url":null,"abstract":"\u0000 The systematic approach adopted by a service company and a Brazilian National Oil Company (NOC) to achieve the goal of safely abandoning wells with different completion types using light workover vessels is discussed. Having determined the abandonment methodology, the service company personnel developed processes and procedures to reach the objective. These include advances in coiled tubing (CT) rigup procedures and using a real-time telemetry system. This approach facilitated the timely and cost effective abandonment of more than 15 wells since 2017 in a safe and environmentally acceptable manner.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126650466","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. Al-Fawwaz, F. Al-Ajmi, K. Razwan, K. Ghosh, Ibrahim Naqeeb, Maria Andrea Torres Portillo
In recent years, as the cost of drilling, evaluating, and completing wells continues to rise in offshore, operators are seeking new technologies that offer measurements comparable to proven wireline logging technologies. Logging while drilling (LWD) technology has progressed swiftly in recent time to address the need for saving rig time by enabling real-time informed decisions for drilling efficiency and risk management. LWD sonic is traditionally used to log formation slowness in the open hole but increasingly being used in cased hole to optimize logging time and evaluate top of cement. Before starting a hole section, well integrity is a critical input to decide if it is safe to drill ahead or additional measures are required to assure operation safety. In this case study we demonstrate that both, measuring formation slowness in open and cased hole along with evaluating the success of a cementing operation can be obtained with the latest generation of LWD sonic tools while drilling, thus saving rig time, simplifying operations, and assuring operation safety and integrity. In this case study we demonstrate that formation slowness can also be recorded in cased hole with LWD tools when the cement bonding is sufficient to allow good coupling. This advanced technique of logging formation slowness through casing with LWD can complement conventional logging, or even save an additional logging run in some cases, and therefore result in significant savings to the operator. Where azimuthal cement evaluation is not a strict requirement, knowing the top-of-cement (TOC) from LWD can help to confirm well integrity without adding rig-time. This in turn will help to take on-time decision to plan additional logging requirements for advanced analysis
{"title":"Drilling to Well Integrity- Multidisciplinary Approach using Advanced Multipole Sonic-While-Drilling Technology Saves Rig Time","authors":"A. Al-Fawwaz, F. Al-Ajmi, K. Razwan, K. Ghosh, Ibrahim Naqeeb, Maria Andrea Torres Portillo","doi":"10.4043/29880-ms","DOIUrl":"https://doi.org/10.4043/29880-ms","url":null,"abstract":"\u0000 In recent years, as the cost of drilling, evaluating, and completing wells continues to rise in offshore, operators are seeking new technologies that offer measurements comparable to proven wireline logging technologies. Logging while drilling (LWD) technology has progressed swiftly in recent time to address the need for saving rig time by enabling real-time informed decisions for drilling efficiency and risk management. LWD sonic is traditionally used to log formation slowness in the open hole but increasingly being used in cased hole to optimize logging time and evaluate top of cement.\u0000 Before starting a hole section, well integrity is a critical input to decide if it is safe to drill ahead or additional measures are required to assure operation safety. In this case study we demonstrate that both, measuring formation slowness in open and cased hole along with evaluating the success of a cementing operation can be obtained with the latest generation of LWD sonic tools while drilling, thus saving rig time, simplifying operations, and assuring operation safety and integrity.\u0000 In this case study we demonstrate that formation slowness can also be recorded in cased hole with LWD tools when the cement bonding is sufficient to allow good coupling. This advanced technique of logging formation slowness through casing with LWD can complement conventional logging, or even save an additional logging run in some cases, and therefore result in significant savings to the operator. Where azimuthal cement evaluation is not a strict requirement, knowing the top-of-cement (TOC) from LWD can help to confirm well integrity without adding rig-time. This in turn will help to take on-time decision to plan additional logging requirements for advanced analysis","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126210624","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}
When we are evaluating reservoirs of very high hydraulic communication, as in the case of several Brazilian pre-salt fields, the identification of the effects of a well, be it source or sink, in other observer wells becomes very complex to be observed. It becomes even more difficult when we do not have control of the volumes that are injected in each zone of interest, uncertainty in the reported flows (mainly of the producers) and difficulty to define a perfect observer point. This work proposes to use the large volume of pressure and flow data that we have available to, through a linear optimization process, identify the hydraulic communication index of each well (producer or injector) at each point of observation. To achieve this objective the author resorts to physical-based data-driven methods, and through linear optimization, reach hydraulical interference coefficients between wells. Those coefficients may delivers relevant, and even unexpected information on how wells are communicated, if there are fractures or vuges unseen by geological methods, and allow the reservoir managing team to anticipates water and/or gas breakthrough, a well is more responsive to which other, etc. Furthermore the methodology may give important information to subsidize the history matching process. The paper shows that the methodology is widely applicable in reservoirs where either the hydraulical communication or the wells densification is high enough to avoid any conclusive assessments from usual methods and has as greatest advantage a strong physical background behind it, unlike several machine learning data driven methods. It will be presented through several examples, applying both in controlled (obtained by synthetically generated data from reservoir flow models) and uncontrolled systems (hard data obtained from Brazilian pre-salt reservoirs).
{"title":"Big Data Approach for Assessing Hydraulic Interference Between Wells in Not-Controled Systems","authors":"V. C. Silva","doi":"10.4043/29881-ms","DOIUrl":"https://doi.org/10.4043/29881-ms","url":null,"abstract":"\u0000 When we are evaluating reservoirs of very high hydraulic communication, as in the case of several Brazilian pre-salt fields, the identification of the effects of a well, be it source or sink, in other observer wells becomes very complex to be observed. It becomes even more difficult when we do not have control of the volumes that are injected in each zone of interest, uncertainty in the reported flows (mainly of the producers) and difficulty to define a perfect observer point. This work proposes to use the large volume of pressure and flow data that we have available to, through a linear optimization process, identify the hydraulic communication index of each well (producer or injector) at each point of observation.\u0000 To achieve this objective the author resorts to physical-based data-driven methods, and through linear optimization, reach hydraulical interference coefficients between wells. Those coefficients may delivers relevant, and even unexpected information on how wells are communicated, if there are fractures or vuges unseen by geological methods, and allow the reservoir managing team to anticipates water and/or gas breakthrough, a well is more responsive to which other, etc. Furthermore the methodology may give important information to subsidize the history matching process.\u0000 The paper shows that the methodology is widely applicable in reservoirs where either the hydraulical communication or the wells densification is high enough to avoid any conclusive assessments from usual methods and has as greatest advantage a strong physical background behind it, unlike several machine learning data driven methods. It will be presented through several examples, applying both in controlled (obtained by synthetically generated data from reservoir flow models) and uncontrolled systems (hard data obtained from Brazilian pre-salt reservoirs).","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130362529","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 study focuses on technical feasibility of producing natural gas from offshore gas hydrate deposits using a new technique called horizontal snake wells (HSW). This paper addresses engineering and well productivity issues for the new technique. Coiled tubing string is proposed to drill HSW in gas hydrate reservoirs for increasing well productivity and reducing wellbore collapse problems. A new analytical model was derived to predict of maximum achievable wellbore length (MAWL) based on the theory of buckling failure. Furui's equation for gas reservoirs was used for predicting the initial well productivity at the MAWL. Gas lift method is proposed to remove water for achieving a constant bottom hole pressure that is slightly below the hydrate dissociation pressure. Gas production forecast was made on the basis of material balance. Net present value (NPV) method is employed to perform economics analysis. A gas hydrate reservoir in the South China Sea was taken as an example to investigate the feasibility of producing natural gas from gas hydrate deposits using the HSW technique. The new analytical model gave the MAWL under extreme well friction conditions prior to buckling failure of coiled tubing. Furui's equation predicted commercial well productivity at the MAWL, depending on the loop separation of the HSW. If the bottom pressure is maintained with gas lift technique at a constant level slightly lower than the hydrate dissociation pressure to prevent wellbore collapse, material balance forecasted high NPV of HSW. It is concluded that the HSW is a feasible technique for economically producing natural gas from offshore gas hydrate deposits. This paper presents a novel method called HSW for producing natural gas from offshore gas hydrate deposits. It also demonstrates how to evaluate the productivity and thus economics of the HSW.
{"title":"A Feasibility Study of Producing Natural Gas from Subsea Hydrates with Horizontal Snake Wells","authors":"L. Wan, R. Shaibu, Xuejun Hou, B. Guo","doi":"10.4043/29816-ms","DOIUrl":"https://doi.org/10.4043/29816-ms","url":null,"abstract":"\u0000 This study focuses on technical feasibility of producing natural gas from offshore gas hydrate deposits using a new technique called horizontal snake wells (HSW). This paper addresses engineering and well productivity issues for the new technique. Coiled tubing string is proposed to drill HSW in gas hydrate reservoirs for increasing well productivity and reducing wellbore collapse problems. A new analytical model was derived to predict of maximum achievable wellbore length (MAWL) based on the theory of buckling failure. Furui's equation for gas reservoirs was used for predicting the initial well productivity at the MAWL. Gas lift method is proposed to remove water for achieving a constant bottom hole pressure that is slightly below the hydrate dissociation pressure. Gas production forecast was made on the basis of material balance. Net present value (NPV) method is employed to perform economics analysis. A gas hydrate reservoir in the South China Sea was taken as an example to investigate the feasibility of producing natural gas from gas hydrate deposits using the HSW technique. The new analytical model gave the MAWL under extreme well friction conditions prior to buckling failure of coiled tubing. Furui's equation predicted commercial well productivity at the MAWL, depending on the loop separation of the HSW. If the bottom pressure is maintained with gas lift technique at a constant level slightly lower than the hydrate dissociation pressure to prevent wellbore collapse, material balance forecasted high NPV of HSW. It is concluded that the HSW is a feasible technique for economically producing natural gas from offshore gas hydrate deposits. This paper presents a novel method called HSW for producing natural gas from offshore gas hydrate deposits. It also demonstrates how to evaluate the productivity and thus economics of the HSW.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134574440","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}
Marine Operations such as pipe laying, subsea installations, heavy lifting operations, work-over operations, crane operations are extremely sensitive to metocean conditions. Wind, wave and currents from different directions and long period wave motion can cause adverse vessel response which may impair operations. Thus, without systematic sea state monitoring, marine operations sensitive to wind, wave height, wave period and vessel motion can be subject to delays, cost overruns, safety issues, and asset damage. Precise knowledge of the sea state during such operations is an essential requirement which has become more critical as offshore activities have moved into ever greater water depths, and into hostile frontier areas. This calls for a reliable and accurate on-board system for continuous, real-time wave and motion monitoring and recording.
{"title":"Dry Sea State Monitoring for More Efficient Marine Operations","authors":"M. Vinther","doi":"10.4043/29952-ms","DOIUrl":"https://doi.org/10.4043/29952-ms","url":null,"abstract":"\u0000 Marine Operations such as pipe laying, subsea installations, heavy lifting operations, work-over operations, crane operations are extremely sensitive to metocean conditions. Wind, wave and currents from different directions and long period wave motion can cause adverse vessel response which may impair operations. Thus, without systematic sea state monitoring, marine operations sensitive to wind, wave height, wave period and vessel motion can be subject to delays, cost overruns, safety issues, and asset damage. Precise knowledge of the sea state during such operations is an essential requirement which has become more critical as offshore activities have moved into ever greater water depths, and into hostile frontier areas. This calls for a reliable and accurate on-board system for continuous, real-time wave and motion monitoring and recording.","PeriodicalId":415055,"journal":{"name":"Day 1 Tue, October 29, 2019","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133482563","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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