B. Dow, Suzett Urbano, Freddy Rojas Rodriguez, Chiradeep Gupta
It is clear the global energy shift toward sustainability is underway. Sentiment is demanding low-carbon energy pursuit at a rate that will require significant investment of infrastructure metamorphosis, while opening new environmental risks that have yet to be determined. For example, electricity storage and transport on the scale required for full conversion away from hydrocarbons would require raw materials sourced in manners that remain ecologically challenging. The oil and gas industry is executing a transformation toward sustainably sourced energy in preparation for this shift. These efforts vary across industry stakeholders, but they are focused on visibly transformative change. However, there remains opportunity to participate in the classic energy supply with a better view toward sustainability by applying technologies that deliver these outcomes. The first important step, however, is to apply the correct key performance objectives (KPOs) and begin measuring the impact of executing with sustainability in mind. This paper will focus in on one drilling technique, managed pressure drilling (MPD), and outline sustainability KPOs applied on case study projects around the world. Classic drilling focuses on performance metrics of time and cost. These metrics, in and of themselves, represent "sustainability" in a sense, but typically are not viewed in that light. Application of MPD, consequently, is weighed with the same. Suppose, however, MPD was evaluated not only on performance KPOs, but also sustainability KPOs. MPD is capable of containment of reservoir fluid and pressure, reduction of drilling fluids and weighting materials, reduction of human energy through applied automation and remote operations, and extension of fields and drilling assets. Packaging and deployment technologies can also reduce emissions during mobilization, execution and demobilization. The work will present a means of defining and measuring the sustainability impact against conventional drilling applications and serve as a roadmap to start the conversation on how the oil and gas industry can make better use of technologies readily available to sustainably deliver oil and gas to the world throughout the energy transition. The primary consumer of energy, the automobile industry, focus significant efforts on fuel efficiency as a KPO. The drilling industry can facilitate a similar shift.
{"title":"Sustainability Metrics for Managed Pressure Drilling","authors":"B. Dow, Suzett Urbano, Freddy Rojas Rodriguez, Chiradeep Gupta","doi":"10.2523/iptc-21986-ms","DOIUrl":"https://doi.org/10.2523/iptc-21986-ms","url":null,"abstract":"\u0000 It is clear the global energy shift toward sustainability is underway. Sentiment is demanding low-carbon energy pursuit at a rate that will require significant investment of infrastructure metamorphosis, while opening new environmental risks that have yet to be determined. For example, electricity storage and transport on the scale required for full conversion away from hydrocarbons would require raw materials sourced in manners that remain ecologically challenging. The oil and gas industry is executing a transformation toward sustainably sourced energy in preparation for this shift. These efforts vary across industry stakeholders, but they are focused on visibly transformative change. However, there remains opportunity to participate in the classic energy supply with a better view toward sustainability by applying technologies that deliver these outcomes. The first important step, however, is to apply the correct key performance objectives (KPOs) and begin measuring the impact of executing with sustainability in mind. This paper will focus in on one drilling technique, managed pressure drilling (MPD), and outline sustainability KPOs applied on case study projects around the world. Classic drilling focuses on performance metrics of time and cost. These metrics, in and of themselves, represent \"sustainability\" in a sense, but typically are not viewed in that light. Application of MPD, consequently, is weighed with the same. Suppose, however, MPD was evaluated not only on performance KPOs, but also sustainability KPOs. MPD is capable of containment of reservoir fluid and pressure, reduction of drilling fluids and weighting materials, reduction of human energy through applied automation and remote operations, and extension of fields and drilling assets. Packaging and deployment technologies can also reduce emissions during mobilization, execution and demobilization.\u0000 The work will present a means of defining and measuring the sustainability impact against conventional drilling applications and serve as a roadmap to start the conversation on how the oil and gas industry can make better use of technologies readily available to sustainably deliver oil and gas to the world throughout the energy transition.\u0000 The primary consumer of energy, the automobile industry, focus significant efforts on fuel efficiency as a KPO. The drilling industry can facilitate a similar shift.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"56 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80210971","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Sarma, J. Rafiee, F. Gutiérrez, C. Calad, Ryan Hilliard, Sebastian Plotno, E. Mamani, O. Angulo, Gabriel Quintero
As the oil and gas industry embarks on the path to energy transition, pressure from government regulators, investors, and the public in general demand that companies have clear and transparent net-zero goals and that their operational initiatives and plans support such transition efforts. Mature fields present an opportunity to increase production through operational optimization, which at the same time, can also lead to greenhouse gas (GHG) emissions efficiency. This paper presents the application of a novel modeling and optimization technique in a mature waterflood environment. Data Physics is the amalgamation of the state-of-the-art in machine learning and the same underlying physics present in reservoir simulators. These models can be created as efficiently as machine learning models, integrate all kinds of data, and can be evaluated orders of magnitude faster than full scale simulation models, and since they include similar underlying physics as simulators, they have good long term predictive capacity and can even be used to predict performance of new wells without any historical data. The technology was applied to a mature field in the Neuquen basin in Argentina to effectively reduce the amount of water injected into the reservoir with no negative impact on the production. Additionally, a new Carbon Intensity (CI) modeling tool was used to compare the emissions intensity before and after optimization showing a significant improvement in CI achieving three objectives in one single decision: 1) obtain significant water injection reduction with its corresponding impact in injection and water treatment costs; 2) maintaining production compared to the initial decline of the field, improving the top line; and 3) improving the GHG emissions intensity hence the long term benefit to the environment. The paper deals more with the implementation of the technologies than the technologies themselves, assuming that readers unfamiliar with both Data Physics and Carbon Intensity tools will refer to the references section to gain familiarity with these.
{"title":"Optimizing a Waterflood Using a Combination of Machine Learning and Reservoir Physics. A Field Application for Reducing Fresh Water Injection with no Impact on Oil Production and Improved Carbon Intensity","authors":"P. Sarma, J. Rafiee, F. Gutiérrez, C. Calad, Ryan Hilliard, Sebastian Plotno, E. Mamani, O. Angulo, Gabriel Quintero","doi":"10.2523/iptc-22406-ea","DOIUrl":"https://doi.org/10.2523/iptc-22406-ea","url":null,"abstract":"\u0000 As the oil and gas industry embarks on the path to energy transition, pressure from government regulators, investors, and the public in general demand that companies have clear and transparent net-zero goals and that their operational initiatives and plans support such transition efforts. Mature fields present an opportunity to increase production through operational optimization, which at the same time, can also lead to greenhouse gas (GHG) emissions efficiency.\u0000 This paper presents the application of a novel modeling and optimization technique in a mature waterflood environment. Data Physics is the amalgamation of the state-of-the-art in machine learning and the same underlying physics present in reservoir simulators. These models can be created as efficiently as machine learning models, integrate all kinds of data, and can be evaluated orders of magnitude faster than full scale simulation models, and since they include similar underlying physics as simulators, they have good long term predictive capacity and can even be used to predict performance of new wells without any historical data. The technology was applied to a mature field in the Neuquen basin in Argentina to effectively reduce the amount of water injected into the reservoir with no negative impact on the production. Additionally, a new Carbon Intensity (CI) modeling tool was used to compare the emissions intensity before and after optimization showing a significant improvement in CI achieving three objectives in one single decision: 1) obtain significant water injection reduction with its corresponding impact in injection and water treatment costs; 2) maintaining production compared to the initial decline of the field, improving the top line; and 3) improving the GHG emissions intensity hence the long term benefit to the environment.\u0000 The paper deals more with the implementation of the technologies than the technologies themselves, assuming that readers unfamiliar with both Data Physics and Carbon Intensity tools will refer to the references section to gain familiarity with these.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"191 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79613093","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. Alzain, Ali Abu Qurain, A. Al-Jaafari, Jason Hall
This paper aims to detail key success factors in understanding the effective principles of managing the health and well-being of the contractor workforce during and post pandemics, specifically for organizations in the oil, gas and energy industry. Furthermore, it shall provide insights and guidance on how to maintain and enhance contractor workforce experience, particularly during and post the COVID-19 pandemic; detailing the benefits of having well-established health management programs designed specifically for the contractor workforce. The social determinants of health (SDH) can be defined as the social and economic conditions in which people are born, grow, live, learn, work and age. They are nonmedical factors that influence a vast range of health conditions; affecting individuals' overall quality-of-life. Economic policies, social norms and political systems are all examples of forces and factors that shape daily life conditions and affect human health (ODPHP, n.d.; WHO, n.d.a). SDH also encompasses education, employment, socioeconomic status, access to health care, social support as well as neighborhood and physical environment (Artiga and Hinton, 2018). SDH have a crucial influence on health disparities and inequities – "the unfair and avoidable differences in health status seen within and between countries" (CDC, 2020). A well-known key factor in the emergence and perpetuation of health disparities is housing. Several researchers from a diverse array of disciplines explored the various aspects of the association between housing, health and well-being. They endeavored to comprehensively elucidate the major pathways through which housing conditions can negatively impact health equity, with a focus on the broad spectrum of hazardous exposures, their accumulated impact and their historical production. As reported by Rolfe et al. (2020), there is compelling evidence of poor physical health consequences of toxins within homes, damp and mold, cold indoor temperatures, overcrowding, and safety factors. Beyond the aforementioned impacts of physical aspects of housing on physical health, poor housing conditions have also been linked with high risks of poor mental health and well-being (Pevalin et al., 2017).
{"title":"The Use of Health Management Programs for the Contractors Workforce","authors":"H. Alzain, Ali Abu Qurain, A. Al-Jaafari, Jason Hall","doi":"10.2523/iptc-22122-ms","DOIUrl":"https://doi.org/10.2523/iptc-22122-ms","url":null,"abstract":"\u0000 This paper aims to detail key success factors in understanding the effective principles of managing the health and well-being of the contractor workforce during and post pandemics, specifically for organizations in the oil, gas and energy industry. Furthermore, it shall provide insights and guidance on how to maintain and enhance contractor workforce experience, particularly during and post the COVID-19 pandemic; detailing the benefits of having well-established health management programs designed specifically for the contractor workforce.\u0000 The social determinants of health (SDH) can be defined as the social and economic conditions in which people are born, grow, live, learn, work and age. They are nonmedical factors that influence a vast range of health conditions; affecting individuals' overall quality-of-life. Economic policies, social norms and political systems are all examples of forces and factors that shape daily life conditions and affect human health (ODPHP, n.d.; WHO, n.d.a). SDH also encompasses education, employment, socioeconomic status, access to health care, social support as well as neighborhood and physical environment (Artiga and Hinton, 2018). SDH have a crucial influence on health disparities and inequities – \"the unfair and avoidable differences in health status seen within and between countries\" (CDC, 2020).\u0000 A well-known key factor in the emergence and perpetuation of health disparities is housing. Several researchers from a diverse array of disciplines explored the various aspects of the association between housing, health and well-being. They endeavored to comprehensively elucidate the major pathways through which housing conditions can negatively impact health equity, with a focus on the broad spectrum of hazardous exposures, their accumulated impact and their historical production. As reported by Rolfe et al. (2020), there is compelling evidence of poor physical health consequences of toxins within homes, damp and mold, cold indoor temperatures, overcrowding, and safety factors. Beyond the aforementioned impacts of physical aspects of housing on physical health, poor housing conditions have also been linked with high risks of poor mental health and well-being (Pevalin et al., 2017).","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"211 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77615209","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}
Y. Bashir, Nordiana MOHD MUZTAZA, Amir Abbas Babasafari, Muhammad Khan, M. Mahgoub, S.Y. Moussavi Alashloo, A. H. Abdul Latiff
Seismic Imaging for the small-scale feature in complex subsurface geology such as Carbonate is not easy to capture because of propagated waves affected by heterogeneous properties of objects in the subsurface. The initial step for machine learning (ML) is to provide enough data which can make our learning algorithm updated and mature. If one has not provided the multiple shapes of diffraction data, then your prediction of ML will be not accurate or even ML not able to detect the pattern of diffraction in the data. After the learning, our machine, the detection of the target is the crucial part that compares with the target and searches the specific signature in the given data. In this paper, we feed it with data in the form of the image and feature. Which can pass through the learning algorithm to predict the target. The idea of ML is to get the difference between your prediction and the target as closely as much possible. Which leads to the better preservation of diffractions amplitude in laterally varying velocity conditions. ML destruction is used for diffraction data separation as the conventional filtering techniques mix the diffraction amplitudes when there are a single or series of diffractions.
{"title":"Machine Learning Application on Seismic Diffraction Detection and Preservation for High Resolution Imaging","authors":"Y. Bashir, Nordiana MOHD MUZTAZA, Amir Abbas Babasafari, Muhammad Khan, M. Mahgoub, S.Y. Moussavi Alashloo, A. H. Abdul Latiff","doi":"10.2523/iptc-21926-ea","DOIUrl":"https://doi.org/10.2523/iptc-21926-ea","url":null,"abstract":"\u0000 Seismic Imaging for the small-scale feature in complex subsurface geology such as Carbonate is not easy to capture because of propagated waves affected by heterogeneous properties of objects in the subsurface. The initial step for machine learning (ML) is to provide enough data which can make our learning algorithm updated and mature. If one has not provided the multiple shapes of diffraction data, then your prediction of ML will be not accurate or even ML not able to detect the pattern of diffraction in the data. After the learning, our machine, the detection of the target is the crucial part that compares with the target and searches the specific signature in the given data. In this paper, we feed it with data in the form of the image and feature. Which can pass through the learning algorithm to predict the target. The idea of ML is to get the difference between your prediction and the target as closely as much possible. Which leads to the better preservation of diffractions amplitude in laterally varying velocity conditions. ML destruction is used for diffraction data separation as the conventional filtering techniques mix the diffraction amplitudes when there are a single or series of diffractions.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"39 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90566813","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. Khan, U. Allauddin, Syed Muhammad Fakhir Hasani, R. Khan, M. Arsalan
Vortex tube that splits a single compressed gas stream into two separate hot and cold streams had been successfully used for spot cooling, and refrigeration. Significant temperature gradient exists between hot and cold stream ends that could be utilized for power generation using thermo-electric generators. Distance between hot and cold ends could be vital for small inaccessible down-hole well locations which may require the use of curved vortex tubes. Efficiency of vortex tube depends on temperature difference between hot and cold ends. In this work, effects of tube curvature on temperature separation efficiency are investigated through numerical simulations. Numerical models of straight and curved vortex tubes are developed in a commercial computational fluid dynamics package Ansys-fluent®. For the curved tube, multiple curvature angles are used to analyze the effects of curvature on velocity and temperature fields inside the vortex tube. The standard κ − ε turbulence model is used to model three-dimensional turbulence. The cold stream mass fraction is varied by controlling hot exit pressure. The numerical results for 110° curved vortex tube are validated through published experimental data and are found to be in good agreement. It is found that the curvature has affirmative results on temperature separation efficiency as compared to straight tube. This is mainly due to the energy separation phenomenon governed by the multi-circulation loop extension and multiple vortex formation in curved vortex tubes. Curvature angles of 180° and 270° have similar effects on the vortex tube where the maximum ΔTc obtained is 15.7 K which is about 5.3% higher than the straight vortex tube. The temperature separation ΔThc values for curved tubes are comparable with straight tube, the maximum being 25.2 K for the 150° curved vortex tube which is about 0.8 per higher than the straight tube. The temperature separation efficiency for curved vortex tubes with curvature angles larger than 150° is found to be higher than straigt tube, the maximum value being 8.7% for the 270° curved tube. A profound investigation of the effects of curvature on energy separation phenomenon in a vortex tube had been lacking and this research attempts to fill that gap. This novel work is expected to provide insight into the energy separation mechanisms in vortex tubes and lead the way to their use in thermo-electric power generation.
{"title":"The Effect of Tube Curvature on Temperature Separation Efficiency of Ranque-Hilsch Vortex Tube","authors":"S. Khan, U. Allauddin, Syed Muhammad Fakhir Hasani, R. Khan, M. Arsalan","doi":"10.2523/iptc-22414-ms","DOIUrl":"https://doi.org/10.2523/iptc-22414-ms","url":null,"abstract":"\u0000 Vortex tube that splits a single compressed gas stream into two separate hot and cold streams had been successfully used for spot cooling, and refrigeration. Significant temperature gradient exists between hot and cold stream ends that could be utilized for power generation using thermo-electric generators. Distance between hot and cold ends could be vital for small inaccessible down-hole well locations which may require the use of curved vortex tubes. Efficiency of vortex tube depends on temperature difference between hot and cold ends. In this work, effects of tube curvature on temperature separation efficiency are investigated through numerical simulations. Numerical models of straight and curved vortex tubes are developed in a commercial computational fluid dynamics package Ansys-fluent®. For the curved tube, multiple curvature angles are used to analyze the effects of curvature on velocity and temperature fields inside the vortex tube. The standard κ − ε turbulence model is used to model three-dimensional turbulence. The cold stream mass fraction is varied by controlling hot exit pressure. The numerical results for 110° curved vortex tube are validated through published experimental data and are found to be in good agreement. It is found that the curvature has affirmative results on temperature separation efficiency as compared to straight tube. This is mainly due to the energy separation phenomenon governed by the multi-circulation loop extension and multiple vortex formation in curved vortex tubes. Curvature angles of 180° and 270° have similar effects on the vortex tube where the maximum ΔTc obtained is 15.7 K which is about 5.3% higher than the straight vortex tube. The temperature separation ΔThc values for curved tubes are comparable with straight tube, the maximum being 25.2 K for the 150° curved vortex tube which is about 0.8 per higher than the straight tube. The temperature separation efficiency for curved vortex tubes with curvature angles larger than 150° is found to be higher than straigt tube, the maximum value being 8.7% for the 270° curved tube. A profound investigation of the effects of curvature on energy separation phenomenon in a vortex tube had been lacking and this research attempts to fill that gap. This novel work is expected to provide insight into the energy separation mechanisms in vortex tubes and lead the way to their use in thermo-electric power generation.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"60 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86019855","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}
Alexandre Javay, Ahmed I. Elbatran, Sunil Sharma, Nata M. Franco, Mauricio Corona, Ahmed A. Alismail
In a deep gas drilling project, the 22-in section across shallow fractured carbonates is drilled using an unweighted clay-water system incorporating up to 50-lbm/bbl bentonite. The main challenges comprise lost circulation, tight hole, and low penetration rates due to high clay content and lack of inhibition, resulting in geological complications and affecting the well delivery time. To seal off the large fractures in the lower-cretaceous limestones, the new drilling fluid was engineered with high thixotropic characteristics presenting a flat, shear-thinning rheological profile with low plastic viscosity, high yield point and flat gel strengths. The selection of candidate wells was supported by offset wells analysis considering drilling performance, penetration rate and footage achieved, and the likelihood of encountering losses. Fine-tuning of the fluid rheology was performed to effectively account for the probability of losses on each well and a fit-for-purpose drilling fluid formulation was designed. This innovative technology combining mixed-metal oxide with premium bentonite was run in a series of wells as a substitute to the previously used system. Due to its superior viscosity at low shear rates the fluid successfully prevented losses by gelling up in the interstices of the highly fractured limestone intervals. In addition, the fluid delivered higher drilling performance across the abrasive sandstone-clay intercalations and the hard carbonates toward the bottom of the section. By maintaining full circulation all way through and therefore avoiding the expenses associated with blind drilling and pumping mud cap, the initiative resulted in considerably lowering the fluid cost in this section. Significant operation time savings were also achieved by drilling the section faster to the intended casing point in a minimum number of runs. Enhanced wellbore condition that allowed the drill string to trip out on elevators instead of back-reaming also contributed to saving rig time. The casing could be run to bottom and cemented trouble free in one stage with cement returns to surface thus precluding the cost of stage collar tool in most of the wells. This paper unveils the facets of this versatile water-base fluid that was introduced as a solution to prevent losses and address poor drilling performance.
{"title":"Use of Mixed-Metal Oxide Water-Based Drilling Fluid System Increased Drilling Performance and Eliminated Mud Losses","authors":"Alexandre Javay, Ahmed I. Elbatran, Sunil Sharma, Nata M. Franco, Mauricio Corona, Ahmed A. Alismail","doi":"10.2523/iptc-21961-ms","DOIUrl":"https://doi.org/10.2523/iptc-21961-ms","url":null,"abstract":"\u0000 In a deep gas drilling project, the 22-in section across shallow fractured carbonates is drilled using an unweighted clay-water system incorporating up to 50-lbm/bbl bentonite. The main challenges comprise lost circulation, tight hole, and low penetration rates due to high clay content and lack of inhibition, resulting in geological complications and affecting the well delivery time.\u0000 To seal off the large fractures in the lower-cretaceous limestones, the new drilling fluid was engineered with high thixotropic characteristics presenting a flat, shear-thinning rheological profile with low plastic viscosity, high yield point and flat gel strengths. The selection of candidate wells was supported by offset wells analysis considering drilling performance, penetration rate and footage achieved, and the likelihood of encountering losses. Fine-tuning of the fluid rheology was performed to effectively account for the probability of losses on each well and a fit-for-purpose drilling fluid formulation was designed.\u0000 This innovative technology combining mixed-metal oxide with premium bentonite was run in a series of wells as a substitute to the previously used system. Due to its superior viscosity at low shear rates the fluid successfully prevented losses by gelling up in the interstices of the highly fractured limestone intervals. In addition, the fluid delivered higher drilling performance across the abrasive sandstone-clay intercalations and the hard carbonates toward the bottom of the section.\u0000 By maintaining full circulation all way through and therefore avoiding the expenses associated with blind drilling and pumping mud cap, the initiative resulted in considerably lowering the fluid cost in this section. Significant operation time savings were also achieved by drilling the section faster to the intended casing point in a minimum number of runs. Enhanced wellbore condition that allowed the drill string to trip out on elevators instead of back-reaming also contributed to saving rig time. The casing could be run to bottom and cemented trouble free in one stage with cement returns to surface thus precluding the cost of stage collar tool in most of the wells. This paper unveils the facets of this versatile water-base fluid that was introduced as a solution to prevent losses and address poor drilling performance.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90928153","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}
To build live-RAM (Reliability, Availability, and Maintainability) model to enable evaluating System Production Availability (PA) associated with variety of shutdown scenarios, with an objective to ensure Production optimization, Reliability improvement, and to support system de-bottlenecking. This Model is complemented by web-based updating tools to reflect changes in Production Profile, Maintenance plans, Reliability and Maintainability data, and equipment modifications.
{"title":"Developing Live RAM Model for Production Availability Evaluation","authors":"Walid Mossa","doi":"10.2523/iptc-22250-ea","DOIUrl":"https://doi.org/10.2523/iptc-22250-ea","url":null,"abstract":"\u0000 \u0000 \u0000 To build live-RAM (Reliability, Availability, and Maintainability) model to enable evaluating System Production Availability (PA) associated with variety of shutdown scenarios, with an objective to ensure Production optimization, Reliability improvement, and to support system de-bottlenecking. This Model is complemented by web-based updating tools to reflect changes in Production Profile, Maintenance plans, Reliability and Maintainability data, and equipment modifications.\u0000","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"78 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75208907","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}
Clement Afagwu, Saad F. K. Al-Afnan, Mohamed Mahmoud, S. Patil
Shale is a type of unconventional reservoir with a significant potential for storing natural gas attributed to its ability to host hydrocarbons as both free and sorbed phases. However, modeling this multi-physics storage capacity requires redefining some macroscopic parameters such as the porosity to capture the adsorption behavior and pore compressibility, which changes over the entire production life of the asset. Besides, a distinct confining stress phenomenon occurs in a reservoir with a different faulting system and degree of stress heterogeneity. Such mechanisms at nanoscale are complex and difficult to isolate through conventional experimental approaches. Alternatively, computational frameworks like molecular simulation can provide a proxy to accurately describe such intervening mechanisms. The study starts with recreating realistic organic matter structures from a given macromolecule kerogen unit using a molecular dynamics protocol. The created structures were subject to adsorption analysis and mechanical properties assessment while tracking the changes in porosity and pore size distribution. The analyses were used to redefine the porosity considering the adsorption behavior, mechanical properties, pore, and confining pressures. Furthermore, a correlation between stress-induced porosity and Langmuir quantities was developed to predict the Langmuir parameters. The logarithmic function-based model showed that a 33.3% change in stress-dependent kerogen porosity could result in a Langmuir amount, pressure and maximum adsorbed gas density variation of around 100%, 100%, and 50% respectively. Consequently, nanoporosity influence on Langmuir parameters should be critically understood as it plays a significant role in adsorbed gas storage and molecular transport processes in organic-rich shale.
{"title":"Langmuir Parameters Prediction: New Insights into the Porosity of the Nanoporous Media of Organic Media of Organic-Rich Shale","authors":"Clement Afagwu, Saad F. K. Al-Afnan, Mohamed Mahmoud, S. Patil","doi":"10.2523/iptc-22670-ms","DOIUrl":"https://doi.org/10.2523/iptc-22670-ms","url":null,"abstract":"\u0000 Shale is a type of unconventional reservoir with a significant potential for storing natural gas attributed to its ability to host hydrocarbons as both free and sorbed phases. However, modeling this multi-physics storage capacity requires redefining some macroscopic parameters such as the porosity to capture the adsorption behavior and pore compressibility, which changes over the entire production life of the asset. Besides, a distinct confining stress phenomenon occurs in a reservoir with a different faulting system and degree of stress heterogeneity. Such mechanisms at nanoscale are complex and difficult to isolate through conventional experimental approaches. Alternatively, computational frameworks like molecular simulation can provide a proxy to accurately describe such intervening mechanisms. The study starts with recreating realistic organic matter structures from a given macromolecule kerogen unit using a molecular dynamics protocol. The created structures were subject to adsorption analysis and mechanical properties assessment while tracking the changes in porosity and pore size distribution. The analyses were used to redefine the porosity considering the adsorption behavior, mechanical properties, pore, and confining pressures. Furthermore, a correlation between stress-induced porosity and Langmuir quantities was developed to predict the Langmuir parameters. The logarithmic function-based model showed that a 33.3% change in stress-dependent kerogen porosity could result in a Langmuir amount, pressure and maximum adsorbed gas density variation of around 100%, 100%, and 50% respectively. Consequently, nanoporosity influence on Langmuir parameters should be critically understood as it plays a significant role in adsorbed gas storage and molecular transport processes in organic-rich shale.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74920239","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}
Multiphase flow is frequently encountered in upstream O&G industry that has significant impact on the development of numerous production technologies such as multiphase flowmeter. Before the deployment of these technologies in an oil/gas field, the technologies are tested in a multiphase industrial flow loop test that emulates multiphase test conditions. This paper presents a digital twin of 2-phase flow (oil & water) as a low cost alternative to expensive multiphase flow test. We have adopted backward strategy to design the digital twin of multiphase flow. At first, we characterized our proprietary microwave water-cut (WC) meter in an industrial flow loop in variable test conditions. Then, multiple digital models of the flow regimes were built and tested on our microwave WC meter. One of those models (rotated zigzag) was able to accurately predict WC sensor response over full WC range in oil continuous as well as water continuous flow conditions under varying salinity levels. Two sets of responses have been recorded and compared – first obtained from the industrial flow loop trials and second from our EM simulation model. Key microwave resonator parameters such as resonant frequency (f0) and quality (Q) factor have been compared under varying conditions. The comparison suggests that f0 & Q-factor give higher sensitivity against WC in oil continuous and water continuous flow conditions respectively. Moreover, WC sensor performance was also compared under varying salinity conditions in the range of 20,000 ppm to 80,000 ppm and digital twin is able to successfully predict the sensor response in these conditions as well. Significant amount of resources are spent on setting desired flow condition such as flow regime, WC and required salinity level. Our proposed digital twin model is able to emulate all of these multiphase flow conditions at negligible cost. It can help develop & test new production technologies without requiring to spend huge amount of money on lengthy, complex and expensive multiphase flow loop tests.
{"title":"Digital Twin of Expensive Multiphase Flow Loop Test to Develop Next Generation of Production Technologies","authors":"M. A. Karimi, M. Arsalan, A. Shamim","doi":"10.2523/iptc-22124-ea","DOIUrl":"https://doi.org/10.2523/iptc-22124-ea","url":null,"abstract":"\u0000 Multiphase flow is frequently encountered in upstream O&G industry that has significant impact on the development of numerous production technologies such as multiphase flowmeter. Before the deployment of these technologies in an oil/gas field, the technologies are tested in a multiphase industrial flow loop test that emulates multiphase test conditions. This paper presents a digital twin of 2-phase flow (oil & water) as a low cost alternative to expensive multiphase flow test.\u0000 We have adopted backward strategy to design the digital twin of multiphase flow. At first, we characterized our proprietary microwave water-cut (WC) meter in an industrial flow loop in variable test conditions. Then, multiple digital models of the flow regimes were built and tested on our microwave WC meter. One of those models (rotated zigzag) was able to accurately predict WC sensor response over full WC range in oil continuous as well as water continuous flow conditions under varying salinity levels.\u0000 Two sets of responses have been recorded and compared – first obtained from the industrial flow loop trials and second from our EM simulation model. Key microwave resonator parameters such as resonant frequency (f0) and quality (Q) factor have been compared under varying conditions. The comparison suggests that f0 & Q-factor give higher sensitivity against WC in oil continuous and water continuous flow conditions respectively. Moreover, WC sensor performance was also compared under varying salinity conditions in the range of 20,000 ppm to 80,000 ppm and digital twin is able to successfully predict the sensor response in these conditions as well.\u0000 Significant amount of resources are spent on setting desired flow condition such as flow regime, WC and required salinity level. Our proposed digital twin model is able to emulate all of these multiphase flow conditions at negligible cost. It can help develop & test new production technologies without requiring to spend huge amount of money on lengthy, complex and expensive multiphase flow loop tests.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"101 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77352025","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}
Oil reservoirs comprise layers of sandstone with oil and gas held in the spaces between the grains that make up the rock. Allowing an oil reservoir to produce oil through declining natural pressure results in relatively low recoveries (10 to 30%), therefore most fields inject water (waterflooding sweeps oil towards the producing wells) into the oil-bearing rocks which typically increase the oil recovery by 5 to 10%. This means only 30 to 40 % of the oil in place is extracted and to further increase recovery various enhanced oil recovery (EOR) techniques are required including: gas-lift, polymer flood, steam injection depending on the reservoir and oil characteristics. In some reservoirs membranes are already used for low sulphate seawater injection to minimizes potential scaling or souring issues due to interactions with the formation rocks or water, however, this is for production maintenance rather than EOR. Waterflooding was first practiced for the purposes of pressure maintenance after primary depletion and displacing oil by taking advantage of viscous forces and has become the most widely adopted improved oil recovery (IOR) technique. Its high availability and simple injection, as well as lower cost and capital investment, are the other key operational and economical features of water flooding. Historically, little attention has been given to the role of injected water chemistry on the displacement efficiency or its recovery. However, over the past decade, many studies have shown that injecting brine with a salinity in the range of 1000–2000 ppm can affect crude oil/brine/rock (COBR) interactions in a favorable manner to reduce the remaining oil saturation.
{"title":"Combinational Membrane Technique to Support Low Salinity Water Flooding Lswf","authors":"M. Sakthivel","doi":"10.2523/iptc-22612-ea","DOIUrl":"https://doi.org/10.2523/iptc-22612-ea","url":null,"abstract":"\u0000 Oil reservoirs comprise layers of sandstone with oil and gas held in the spaces between the grains that make up the rock. Allowing an oil reservoir to produce oil through declining natural pressure results in relatively low recoveries (10 to 30%), therefore most fields inject water (waterflooding sweeps oil towards the producing wells) into the oil-bearing rocks which typically increase the oil recovery by 5 to 10%. This means only 30 to 40 % of the oil in place is extracted and to further increase recovery various enhanced oil recovery (EOR) techniques are required including: gas-lift, polymer flood, steam injection depending on the reservoir and oil characteristics. In some reservoirs membranes are already used for low sulphate seawater injection to minimizes potential scaling or souring issues due to interactions with the formation rocks or water, however, this is for production maintenance rather than EOR.\u0000 Waterflooding was first practiced for the purposes of pressure maintenance after primary depletion and displacing oil by taking advantage of viscous forces and has become the most widely adopted improved oil recovery (IOR) technique. Its high availability and simple injection, as well as lower cost and capital investment, are the other key operational and economical features of water flooding.\u0000 Historically, little attention has been given to the role of injected water chemistry on the displacement efficiency or its recovery. However, over the past decade, many studies have shown that injecting brine with a salinity in the range of 1000–2000 ppm can affect crude oil/brine/rock (COBR) interactions in a favorable manner to reduce the remaining oil saturation.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74554438","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：