There are a few studies covering solid-particles transport in multiphase pipelines. Solid-particles transport is complicated because it depends on several variables, including flow patterns, fluid properties, phase velocities, and pipe-geometry features such as roughness, diameter, and inclination angle. Each of these variables can have significant effects on the solid-particles-transport process. More attention has been paid recently to the importance of tracking solid-particles-transport management over reservoir life. There are three options available for managing solid-particles transport: applying a cleaning operation, installing solid-particles exclusion facilities, and operating above the critical solid-particles-deposition velocity. Cleaning operations, such as pigging, are only applicable for small amounts of solid particles, and they often result in the pig becoming stuck if the pigging frequency is not high enough. Installing solid-particles exclusion systems (e.g., gravel packs) can reduce production and create excessive pressure drops. The third option, operating above the critical solid-particles-deposition velocity, is preferred for solid-particles-production management as a prevention technique under favorable operating conditions because it has practical applications and can be beneficial commercially. To avoid solid-particles deposition, it is necessary to manage solid-particles transport above solid-particles-deposition velocities. On the other hand, operating under unnecessarily high flow rates is not only cost inefficient, but can also create facility damages; therefore, it is necessary to find the optimum velocity to maintain continuous particle movement. This velocity is called the critical solid-particles-deposition velocity.
{"title":"Solid-Particles Flow Regimes in Air/Water Stratified Flow in a Horizontal Pipeline","authors":"Ramin Dabirian, R. Mohan, O. Shoham, G. Kouba","doi":"10.2118/174960-PA","DOIUrl":"https://doi.org/10.2118/174960-PA","url":null,"abstract":"There are a few studies covering solid-particles transport in multiphase pipelines. Solid-particles transport is complicated because it depends on several variables, including flow patterns, fluid properties, phase velocities, and pipe-geometry features such as roughness, diameter, and inclination angle. Each of these variables can have significant effects on the solid-particles-transport process. More attention has been paid recently to the importance of tracking solid-particles-transport management over reservoir life. There are three options available for managing solid-particles transport: applying a cleaning operation, installing solid-particles exclusion facilities, and operating above the critical solid-particles-deposition velocity. Cleaning operations, such as pigging, are only applicable for small amounts of solid particles, and they often result in the pig becoming stuck if the pigging frequency is not high enough. Installing solid-particles exclusion systems (e.g., gravel packs) can reduce production and create excessive pressure drops. The third option, operating above the critical solid-particles-deposition velocity, is preferred for solid-particles-production management as a prevention technique under favorable operating conditions because it has practical applications and can be beneficial commercially. To avoid solid-particles deposition, it is necessary to manage solid-particles transport above solid-particles-deposition velocities. On the other hand, operating under unnecessarily high flow rates is not only cost inefficient, but can also create facility damages; therefore, it is necessary to find the optimum velocity to maintain continuous particle movement. This velocity is called the critical solid-particles-deposition velocity.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"196 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86660246","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}
ally defined as a permanent permeability reduction after the HPAM solution flows through the porous media), a water-phase velocity, and a lower mobility ratio between the water and oil phases (Wu et al. 2012; Zhang et al. 2015). All these allow higher oil recovery from the larger reservoir volume swept and higher oil-displacement efficiency with polymer fluids. Evidence from pilot tests in the Daqing oil field clearly demonstrates the feasibility and superiority of the HCPF method, which is worth pursuing (Yang et al. 2006b; Denney 2009; Zhu et al. 2013). Yang et al. (2006a) also used high-concentration HPAM solution to conduct flooding studies for a Canadian oil field and illustrated the promising effect of HPAM, showing that it can increase the recovery factor to 21% of original oil in place (OOIP), even though, during the process of HCPF, the oil/water mixture is more easily emulsified and is separated with more difficulty because more HPAM is produced with the liquid. Emulsifications are ubiquitous in oil-production operations, and they are often responsible for oil-productivity impairment and increased production costs associated with transportation and separation, which are more serious in the HCPF process. Emulsions formed without addition of particles or chemicals might be stabilized by polar components in the crude oil such as resins and asphaltenes. Numerous publications have reported that a number of factors could impact the emulsion stability. McLean and Kilpatrick (1997) studied the role of asphaltenes and their interactions with the resins and surrounding crude media in forming interfacial films leading to emulsion stability. Grutters et al. (2007) observed that polar resins, such as naphthenic acids, play an important role in stabilizing the emulsions. Liu et al. (2002) used zeta-potential measurements to study the interaction between bitumen and clay in aqueous solutions. Yang et al. (2007) studied the stability of paraffin/water emulsions, and they argued that the adsorption of particles at interfaces may be controlled by adjusting the electrostatic interaction between particles and the interface without changing hydrophobicity, which is thought to be a main controlling factor of emulsion type and stability. Wang and Alvarado (2008) sampled aqueous phase and oil from a Wyoming reservoir and studied the effect of salinity and pH on emulsion stability. The role of polymer is to further provide stabilization conditions for emulsions, leading to more-complex emulsification behavior. Rigidity of the water/oil interface has been attributed to significant contributions to the suppression of films, hence limiting coalescence. In other words, the rigidity of the surface that is reflected by the rheology is not controlled by interfacial tension in these stable emulsions. At the same time, significant effort has been dedicated to designing protocols to break up harmful emulsions in oil production (Kokal 2005; Nasiri et al. 2013; Liu et al.
{"title":"Case History of Dehydration-Technology Improvement for HCPF Production in the Daqing Oil Field","authors":"Zhihua Wang, Xinyu Lin, Tianyu Yu, Zhiwei Hu, Mengmeng Xu, Hongtao Yu","doi":"10.2118/172768-PA","DOIUrl":"https://doi.org/10.2118/172768-PA","url":null,"abstract":"ally defined as a permanent permeability reduction after the HPAM solution flows through the porous media), a water-phase velocity, and a lower mobility ratio between the water and oil phases (Wu et al. 2012; Zhang et al. 2015). All these allow higher oil recovery from the larger reservoir volume swept and higher oil-displacement efficiency with polymer fluids. Evidence from pilot tests in the Daqing oil field clearly demonstrates the feasibility and superiority of the HCPF method, which is worth pursuing (Yang et al. 2006b; Denney 2009; Zhu et al. 2013). Yang et al. (2006a) also used high-concentration HPAM solution to conduct flooding studies for a Canadian oil field and illustrated the promising effect of HPAM, showing that it can increase the recovery factor to 21% of original oil in place (OOIP), even though, during the process of HCPF, the oil/water mixture is more easily emulsified and is separated with more difficulty because more HPAM is produced with the liquid. Emulsifications are ubiquitous in oil-production operations, and they are often responsible for oil-productivity impairment and increased production costs associated with transportation and separation, which are more serious in the HCPF process. Emulsions formed without addition of particles or chemicals might be stabilized by polar components in the crude oil such as resins and asphaltenes. Numerous publications have reported that a number of factors could impact the emulsion stability. McLean and Kilpatrick (1997) studied the role of asphaltenes and their interactions with the resins and surrounding crude media in forming interfacial films leading to emulsion stability. Grutters et al. (2007) observed that polar resins, such as naphthenic acids, play an important role in stabilizing the emulsions. Liu et al. (2002) used zeta-potential measurements to study the interaction between bitumen and clay in aqueous solutions. Yang et al. (2007) studied the stability of paraffin/water emulsions, and they argued that the adsorption of particles at interfaces may be controlled by adjusting the electrostatic interaction between particles and the interface without changing hydrophobicity, which is thought to be a main controlling factor of emulsion type and stability. Wang and Alvarado (2008) sampled aqueous phase and oil from a Wyoming reservoir and studied the effect of salinity and pH on emulsion stability. The role of polymer is to further provide stabilization conditions for emulsions, leading to more-complex emulsification behavior. Rigidity of the water/oil interface has been attributed to significant contributions to the suppression of films, hence limiting coalescence. In other words, the rigidity of the surface that is reflected by the rheology is not controlled by interfacial tension in these stable emulsions. At the same time, significant effort has been dedicated to designing protocols to break up harmful emulsions in oil production (Kokal 2005; Nasiri et al. 2013; Liu et al. ","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"162 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84991227","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}
and showed that large eddy simulation (LES) was better suited than k–ε based models for predicting the temperature profile. However, the experimental temperature data were obtained solely for the pipe wall, and the velocity field and the thermal field inside the pipe were not investigated. In a study by Jensen and Grafsrønningen (2014), a 3-hour-long cooldown experiment was conducted on a water-filled T-shaped acrylic-glass pipe, representing a production header with a vertical deadleg. The header was insulated, while the deadleg was kept uninsulated. The T-shaped pipe dimensions were representative of a subsea production pipe, but unlike a subsea pipeline, the experiment was set up with air at room temperature as the surrounding medium. Temperatures in the T-shaped pipe were measured internally with RTDs and externally with pipe-wall-mounted thermocouples, while velocity data were obtained in the deadleg by use of PIV. These measurements were used as benchmark data to establish a suitable numerical model. The study scrutinized the accuracy of standard RANS turbulence models in predicting the flow kinematics inside the vertical deadleg when the flow was both turbulent along the pipe wall and laminar closer to the center of the pipe at the same time. Mesh independent results were obtained by running a series of mesh convergence tests. It was shown that cooldown simulations were more sensitive to mesh design than the choice of turbulence model. Mean velocities in the deadleg compared well with experimental PIV data during the first 60 minutes, but the RANS model was not able to predict the laminar-flow kinematics that occurred after this time. The thermal field was correctly predicted with a RANS model for 3 hours of cooldown, even though the flow was laminar in the entire deadleg after 60 minutes. The heat loss in the experiment was limited by the heat-transfer rate to the surrounding air, and not by the internal natural convection. Thus, the accuracy of the RANS model for predicting the internal flow kinematics was not essential for calculating the cooldown times. Rayleigh-Benard convection in enclosures, where a fluid is heated from the bottom and cooled from above, has been the topic of many research papers. Recent experimental, numerical, and theoretical advances in Rayleigh-Benard convection were presented in Chillà and Schumacher (2012). The paper scrutinized experimental and numerical data from a series of publications on RayleighBenard convection in cylindrical enclosures. The underlying studies differed in terms of the temperature gradient between the top and bottom plate, the fluid inside the enclosure, and the aspect ratio Γ = L/H of the enclosure, where L is the characteristic length and H is the height of the enclosure. For 107 ≤ Ra ≤ 1012, the authors showed how large-scale convection (LSC) inside the enclosure influences the overall heat loss in the system. LSC refers to the tendency for thermal plumes of the same type to cluster to
{"title":"Cooldown of Subsea Deadleg With a Cold Spot: Experimental and Numerical Heat-Transfer Analysis","authors":"O. Hagemann, A. Jensen, Stig Grafsrønningen","doi":"10.2118/185170-PA","DOIUrl":"https://doi.org/10.2118/185170-PA","url":null,"abstract":"and showed that large eddy simulation (LES) was better suited than k–ε based models for predicting the temperature profile. However, the experimental temperature data were obtained solely for the pipe wall, and the velocity field and the thermal field inside the pipe were not investigated. In a study by Jensen and Grafsrønningen (2014), a 3-hour-long cooldown experiment was conducted on a water-filled T-shaped acrylic-glass pipe, representing a production header with a vertical deadleg. The header was insulated, while the deadleg was kept uninsulated. The T-shaped pipe dimensions were representative of a subsea production pipe, but unlike a subsea pipeline, the experiment was set up with air at room temperature as the surrounding medium. Temperatures in the T-shaped pipe were measured internally with RTDs and externally with pipe-wall-mounted thermocouples, while velocity data were obtained in the deadleg by use of PIV. These measurements were used as benchmark data to establish a suitable numerical model. The study scrutinized the accuracy of standard RANS turbulence models in predicting the flow kinematics inside the vertical deadleg when the flow was both turbulent along the pipe wall and laminar closer to the center of the pipe at the same time. Mesh independent results were obtained by running a series of mesh convergence tests. It was shown that cooldown simulations were more sensitive to mesh design than the choice of turbulence model. Mean velocities in the deadleg compared well with experimental PIV data during the first 60 minutes, but the RANS model was not able to predict the laminar-flow kinematics that occurred after this time. The thermal field was correctly predicted with a RANS model for 3 hours of cooldown, even though the flow was laminar in the entire deadleg after 60 minutes. The heat loss in the experiment was limited by the heat-transfer rate to the surrounding air, and not by the internal natural convection. Thus, the accuracy of the RANS model for predicting the internal flow kinematics was not essential for calculating the cooldown times. Rayleigh-Benard convection in enclosures, where a fluid is heated from the bottom and cooled from above, has been the topic of many research papers. Recent experimental, numerical, and theoretical advances in Rayleigh-Benard convection were presented in Chillà and Schumacher (2012). The paper scrutinized experimental and numerical data from a series of publications on RayleighBenard convection in cylindrical enclosures. The underlying studies differed in terms of the temperature gradient between the top and bottom plate, the fluid inside the enclosure, and the aspect ratio Γ = L/H of the enclosure, where L is the characteristic length and H is the height of the enclosure. For 107 ≤ Ra ≤ 1012, the authors showed how large-scale convection (LSC) inside the enclosure influences the overall heat loss in the system. LSC refers to the tendency for thermal plumes of the same type to cluster to","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"2012 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87713251","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}
{"title":"Ecological and Environmental Management During the Hail 3D Transition-Zone Survey: Safe Working Practices Within a UNESCO World-Biosphere Reserve","authors":"G. S. MacGlennon, P. Nilsson, G. Casson","doi":"10.2118/177780-PA","DOIUrl":"https://doi.org/10.2118/177780-PA","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84182492","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}
J. Fång, X. Meng, Guoling Xu, Yong Yue, Peichao Cong, C. Xiao, Wenhui Guo
tive steps toward reducing their environmental footprints (Permata and McBride 2010) by use of several waste-treatment alternatives, including injection (Mkpaoro et al. 2015; Ntukidem et al. 2002), bioremediation (Ozumba and Benebo 2002), solidification stabilization (Segret et al. 2007), and thermal desorption. Although injection could dispose of the oily waste validly, its main issue is the lifetime of the injection well, which is limited to its application. The limitation of bioremediation is the slow process rate, requiring space and maintenance up to 1 year. With the solidification-stabilization method, there is a risk of potential leaching, and, in addition, the hydrocarbons cannot be recovered, resulting in waste of a useful resource. To maximize hydrocarbon recovery without noticeable impact on the environment, thermal desorption (Agha and Irrechukwu 2002), originating from the early 1990s (Gilpin 2014), is considered the optimal technology for future use (Seaton and Browning 2005) because it is environmentally clean and can be applied to varying levels of contamination (Hahn 1994). More importantly, the hydrocarbons can be recovered, reducing economic cost (Al-Suwaidi et al. 2004; Fang et al. 2007). It is generally found, however, that the recovered hydrocarbons from thermal-desorption technology present a pungent odor, resulting from the presence of sulfur and nitrogen compounds. The odor has not only restricted seriously the reuse of recovered hydrocarbons, but has also threatened the environment. The aim of this paper is to present a TDU with an odor-treatment system for eliminating the pungent odor from recovered hydrocarbons.
采取措施减少环境足迹(Permata和McBride 2010)，通过使用几种废物处理替代品，包括注射(Mkpaoro等，2015;Ntukidem et al. 2002)、生物修复(Ozumba and Benebo 2002)、固化稳定(Segret et al. 2007)和热解吸。虽然注入可以有效地处理含油废弃物，但其主要问题是注入井的寿命，这受其应用的限制。生物修复的限制是处理速度慢，需要长达1年的空间和维护。使用固化-稳定方法，存在潜在浸出的风险，此外，碳氢化合物无法回收，导致有用资源的浪费。为了在不显著影响环境的情况下最大限度地提高碳氢化合物的采收率，热解吸技术(Agha和rechukwu 2002)起源于20世纪90年代初(Gilpin 2014)，被认为是未来使用的最佳技术(Seaton和Browning 2005)，因为它对环境清洁，可以应用于不同程度的污染(Hahn 1994)。更重要的是，可以回收碳氢化合物，降低经济成本(al - suwaidi et al. 2004;Fang et al. 2007)。然而，通常发现，从热解吸技术中回收的碳氢化合物由于存在硫和氮化合物而呈现出刺鼻的气味。恶臭不仅严重限制了回收烃类的再利用，而且对环境造成了威胁。本文的目的是提出一种带有气味处理系统的TDU，用于消除回收碳氢化合物的刺鼻气味。
{"title":"Odor-Treatment Technology for Recovered Hydrocarbons From Oily Waste in a Thermal-Desorption Unit","authors":"J. Fång, X. Meng, Guoling Xu, Yong Yue, Peichao Cong, C. Xiao, Wenhui Guo","doi":"10.2118/184399-PA","DOIUrl":"https://doi.org/10.2118/184399-PA","url":null,"abstract":"tive steps toward reducing their environmental footprints (Permata and McBride 2010) by use of several waste-treatment alternatives, including injection (Mkpaoro et al. 2015; Ntukidem et al. 2002), bioremediation (Ozumba and Benebo 2002), solidification stabilization (Segret et al. 2007), and thermal desorption. Although injection could dispose of the oily waste validly, its main issue is the lifetime of the injection well, which is limited to its application. The limitation of bioremediation is the slow process rate, requiring space and maintenance up to 1 year. With the solidification-stabilization method, there is a risk of potential leaching, and, in addition, the hydrocarbons cannot be recovered, resulting in waste of a useful resource. To maximize hydrocarbon recovery without noticeable impact on the environment, thermal desorption (Agha and Irrechukwu 2002), originating from the early 1990s (Gilpin 2014), is considered the optimal technology for future use (Seaton and Browning 2005) because it is environmentally clean and can be applied to varying levels of contamination (Hahn 1994). More importantly, the hydrocarbons can be recovered, reducing economic cost (Al-Suwaidi et al. 2004; Fang et al. 2007). It is generally found, however, that the recovered hydrocarbons from thermal-desorption technology present a pungent odor, resulting from the presence of sulfur and nitrogen compounds. The odor has not only restricted seriously the reuse of recovered hydrocarbons, but has also threatened the environment. The aim of this paper is to present a TDU with an odor-treatment system for eliminating the pungent odor from recovered hydrocarbons.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"50 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77686442","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. Akbary, Seyed H. Mousavi Khoshdel, Mohammad Azari, A. Saeedi, M. Hosseinzadeh, A. Ehsaninejad, G. Bahmannia, D. Babu
{"title":"Thermal Regime Effect on Gas-Transport Lines in the Persian Gulf","authors":"H. Akbary, Seyed H. Mousavi Khoshdel, Mohammad Azari, A. Saeedi, M. Hosseinzadeh, A. Ehsaninejad, G. Bahmannia, D. Babu","doi":"10.2118/185176-PA","DOIUrl":"https://doi.org/10.2118/185176-PA","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85330550","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}
{"title":"Spatial Analysis of Horizontal-Shale-Well Water Production in the Wattenberg Field","authors":"B. Bai, K. Carlson","doi":"10.2118/185964-PA","DOIUrl":"https://doi.org/10.2118/185964-PA","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"170 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83895322","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}
plex pipeline network. Furthermore, existing studies assume only single partial blockage in the pipeline, which limits the application of available models because the detection will be misleading if there is more than one partial blockage in the pipeline. To fill this gap, we developed a model to differentiate the single-partialblockage scenario from the multiple-partial-blockage scenario on the basis of multirate tests. The identification is critical because it guides partial-blockage detection in the right direction.
{"title":"A New Method To Detect Partial Blockage in Gas Pipelines","authors":"Kegang Ling, Xingru Wu, Zheng Shen","doi":"10.2118/174751-PA","DOIUrl":"https://doi.org/10.2118/174751-PA","url":null,"abstract":"plex pipeline network. Furthermore, existing studies assume only single partial blockage in the pipeline, which limits the application of available models because the detection will be misleading if there is more than one partial blockage in the pipeline. To fill this gap, we developed a model to differentiate the single-partialblockage scenario from the multiple-partial-blockage scenario on the basis of multirate tests. The identification is critical because it guides partial-blockage detection in the right direction.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87529278","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. Yonebayashi, Katsumo Takabayashi, R. Iizuka, S. Tosic
have complexity of technical evaluation. Such complexity might be encountered when assuming an emerging condition or when introducing emerging technologies. In such cases, potential concepts are often difficult to evaluate fairly with existing technologies, but can possibly be evaluated with newly introduced or developing evaluation measures. However, these new and developing measures require cost that can be justified at the matured stage of development, but that cannot be justified at the concept-screening stage. In the future, the exploration and production (E&P) industry will be required to access more emerging fields of lesser easy oil; thus, this case study will be an example engaging a similar situation.
{"title":"Managing Experimental-Data Shortfalls for Fair Screening at Concept Selection: Case Study To Estimate How Acid-Gas Injection Affects Asphaltene-Precipitation Behavior","authors":"H. Yonebayashi, Katsumo Takabayashi, R. Iizuka, S. Tosic","doi":"10.2118/170585-PA","DOIUrl":"https://doi.org/10.2118/170585-PA","url":null,"abstract":"have complexity of technical evaluation. Such complexity might be encountered when assuming an emerging condition or when introducing emerging technologies. In such cases, potential concepts are often difficult to evaluate fairly with existing technologies, but can possibly be evaluated with newly introduced or developing evaluation measures. However, these new and developing measures require cost that can be justified at the matured stage of development, but that cannot be justified at the concept-screening stage. In the future, the exploration and production (E&P) industry will be required to access more emerging fields of lesser easy oil; thus, this case study will be an example engaging a similar situation.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"2675 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81772788","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}
paper is written from a psychological perspective, though it tries to illustrate the argument with examples relevant to oil and gas operations. While there have been previous attempts to apply this area of knowledge to the analysis of real-world incidents (see, for example, Thorogood et al. 2014; Crichton and Thorogood 2015) and to develop operational interventions (McLeod and Beckett 2012), such attempts have been limited to date, and have lacked the necessary research evidence. There is a compelling need to understand better how these psychological processes actually influence realworld operations, and to develop practical approaches to mitigating the associated risks.
这篇论文是从心理学的角度出发的，尽管它试图用与石油和天然气作业相关的例子来说明这一论点。虽然之前曾有人尝试将这一领域的知识应用于现实世界事件的分析(例如，见Thorogood等人2014;Crichton and Thorogood 2015)以及开发操作干预措施(McLeod and Beckett 2012)，迄今为止，此类尝试受到限制，并且缺乏必要的研究证据。迫切需要更好地了解这些心理过程实际上如何影响现实世界的操作，并制定切实可行的方法来减轻相关风险。
{"title":"The Impact of Styles of Thinking and Cognitive Bias on How People Assess Risk and Make Real-World Decisions in Oil and Gas Operations","authors":"R. Mcleod","doi":"10.2118/179197-PA","DOIUrl":"https://doi.org/10.2118/179197-PA","url":null,"abstract":"paper is written from a psychological perspective, though it tries to illustrate the argument with examples relevant to oil and gas operations. While there have been previous attempts to apply this area of knowledge to the analysis of real-world incidents (see, for example, Thorogood et al. 2014; Crichton and Thorogood 2015) and to develop operational interventions (McLeod and Beckett 2012), such attempts have been limited to date, and have lacked the necessary research evidence. There is a compelling need to understand better how these psychological processes actually influence realworld operations, and to develop practical approaches to mitigating the associated risks.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2016-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86378168","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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