One of the main challenges in the execution of regional studies is the integration of large amounts of data coming from different sources and different disciplines. Even within the geophysical domain, integration of thousands of 2D seismic lines and dozens of 3D seismic volumes is a very demanding task. The aim of this paper is to provide a description on the use of fast track methodologies for the integration of 3D and 2D seismic data at country level for regional studies. This approach relies on a pragmatic way of merging seismic, processing data as point sets instead of traces, providing the flexibility of handling seismic information inside the geomodelling and geostatistical domain, where a grid of points can be resampled, reoriented, and ultimately merged into any desired geometry and resolution. The technical challenges include different spatial sampling, grid orientations, frequency contents and event timings. A preconditioning step has been included in the workflow in order to homogenize the data into a common ground, addressing compatibility issues of the different vintages through amplitude scaling, noise reduction and frequency balancing. Merging in a practical approach different 2D/3D seismic data sets into a single volume reduces drastically the amount of time spent in the data analysis and interpretation of geological features at regional scale. In this case of study, the workflow enables a feasible path for merging all seismic data acquired in Abu Dhabi over the past seven decades. The integrated volume helps geophysicists and geologists to carry out better seismic interpretations and perform proper structural analysis and prospect assessments. Finally, the seismic data has been integrated into a unique survey by interpolating the 2D and 3D seismic data to fill the gaps and generating a pseudo 3D survey at country scale. This regional scale single 3D seismic data allows better understanding of the geological and structural trends present in Abu Dhabi. This innovative approach offers a major advantage for regional data integration, expediting subsequent stages of seismic interpretation and description of the geological features at large scale for exploration assessments, prospect generation and 3D reservoir characterization.
{"title":"First Abu Dhabi 2D/3D Seismic Merge. Fast Track Approach For Seismic Data Integration at Regional Scale in Exploration Studies","authors":"Humberto Parra, M. Caeiro, F. Neves, J. Gomes","doi":"10.2118/193066-MS","DOIUrl":"https://doi.org/10.2118/193066-MS","url":null,"abstract":"\u0000 One of the main challenges in the execution of regional studies is the integration of large amounts of data coming from different sources and different disciplines. Even within the geophysical domain, integration of thousands of 2D seismic lines and dozens of 3D seismic volumes is a very demanding task. The aim of this paper is to provide a description on the use of fast track methodologies for the integration of 3D and 2D seismic data at country level for regional studies.\u0000 This approach relies on a pragmatic way of merging seismic, processing data as point sets instead of traces, providing the flexibility of handling seismic information inside the geomodelling and geostatistical domain, where a grid of points can be resampled, reoriented, and ultimately merged into any desired geometry and resolution. The technical challenges include different spatial sampling, grid orientations, frequency contents and event timings. A preconditioning step has been included in the workflow in order to homogenize the data into a common ground, addressing compatibility issues of the different vintages through amplitude scaling, noise reduction and frequency balancing.\u0000 Merging in a practical approach different 2D/3D seismic data sets into a single volume reduces drastically the amount of time spent in the data analysis and interpretation of geological features at regional scale. In this case of study, the workflow enables a feasible path for merging all seismic data acquired in Abu Dhabi over the past seven decades. The integrated volume helps geophysicists and geologists to carry out better seismic interpretations and perform proper structural analysis and prospect assessments. Finally, the seismic data has been integrated into a unique survey by interpolating the 2D and 3D seismic data to fill the gaps and generating a pseudo 3D survey at country scale. This regional scale single 3D seismic data allows better understanding of the geological and structural trends present in Abu Dhabi.\u0000 This innovative approach offers a major advantage for regional data integration, expediting subsequent stages of seismic interpretation and description of the geological features at large scale for exploration assessments, prospect generation and 3D reservoir characterization.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85508663","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}
Abby Kalio Amabipi, M. Salem, S. P. Grandhe, Tijender Kumar Gupta, M. Awah, J. Schell, T. Compton, N. Herbig
Internal corrosion in high pressure water injection flow lines is a very serious problem in the ADNOC super gigantic onshore fields. This issue has resulted in frequent pipe leaks and water injection flow lines outage which adversely affected oil and gas production due to failure in meeting the required water injection. This paper illustrates successful cost efficient innovative application strategy of the HDPE Liner technology in mitigating internal corrosion problems in water injection flow lines. Innovation centers of some petrochemical companies have now made available "BIMODAL PE100 POLYETHYLENE" materials which are suited for high pressure pipes and able to provide extra flexibility and safety in case of surface scratches in highly deviated flow lines. This paper presents the detailed preparation of the HDPE material, installation, intensive monitoring program, results and integrity challenges of the technology validation in 3km pipeline. A rolling machine reduced the OD of HDPE liner by 7% before drawing into the flow line by a pulling machine, the HDPE OD expands back to full size to give a tight fit in the flow line after sometime. The field trial was initiated in June of 2011 and actual installation completed in two weeks. The Liner conditions were monitored from 2011 through 2017. The flow line section protected with HDPE liner still operates in excellent conditions without any sign of corrosion up till date. This is a technology break through that eliminated internal corrosion threats with huge Opex savings in chemical treatment programs as no chemicals were applied. This Technology is now at the implementation stage in the ADNOC super gigantic onshore field. The paper elaborate on the value added to the company and possible areas of application of the technology for maximum benefits. Finally, this technology has clear impact on the internal corrosion management process that guarantees proper flow line long-life innovative design strategy and provides alternative solutions to conventional flow line designs.
{"title":"Corrosion Management, Field Trial Results of High Pressure Black Bimodal PE100 HDPE Liner in a Super Gigantic Field Provides Innovative Strategy for High Pressure Water Injection Flow Line Internal Corrosion Management","authors":"Abby Kalio Amabipi, M. Salem, S. P. Grandhe, Tijender Kumar Gupta, M. Awah, J. Schell, T. Compton, N. Herbig","doi":"10.2118/192894-MS","DOIUrl":"https://doi.org/10.2118/192894-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Internal corrosion in high pressure water injection flow lines is a very serious problem in the ADNOC super gigantic onshore fields. This issue has resulted in frequent pipe leaks and water injection flow lines outage which adversely affected oil and gas production due to failure in meeting the required water injection. This paper illustrates successful cost efficient innovative application strategy of the HDPE Liner technology in mitigating internal corrosion problems in water injection flow lines.\u0000 \u0000 \u0000 \u0000 Innovation centers of some petrochemical companies have now made available \"BIMODAL PE100 POLYETHYLENE\" materials which are suited for high pressure pipes and able to provide extra flexibility and safety in case of surface scratches in highly deviated flow lines. This paper presents the detailed preparation of the HDPE material, installation, intensive monitoring program, results and integrity challenges of the technology validation in 3km pipeline. A rolling machine reduced the OD of HDPE liner by 7% before drawing into the flow line by a pulling machine, the HDPE OD expands back to full size to give a tight fit in the flow line after sometime.\u0000 \u0000 \u0000 \u0000 The field trial was initiated in June of 2011 and actual installation completed in two weeks. The Liner conditions were monitored from 2011 through 2017. The flow line section protected with HDPE liner still operates in excellent conditions without any sign of corrosion up till date. This is a technology break through that eliminated internal corrosion threats with huge Opex savings in chemical treatment programs as no chemicals were applied. This Technology is now at the implementation stage in the ADNOC super gigantic onshore field.\u0000 \u0000 \u0000 \u0000 The paper elaborate on the value added to the company and possible areas of application of the technology for maximum benefits. Finally, this technology has clear impact on the internal corrosion management process that guarantees proper flow line long-life innovative design strategy and provides alternative solutions to conventional flow line designs.\u0000","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"162 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88054545","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}
All present time, most of downhole electrical devices operate either retrievable "rechargeable batteries" or permanent electric or fiber cable extend from surface till the bottom associated with high risk and high cost operations. Commonly both retrievable and permanent devices have advantage such as live data and easy communication. However, the disadvantages are temperature limitation, high cost, high risk, and restrictions moreover not suit many other completion scenarios and wells completion types. Most of memory gauges could read with 5 sec rate up to 43 days in temperature range 150 C, and it will reduce to 18 days when temperature increase up to 200 C. even increasing the time by reducing number of decimals for the recorded values. However, memory gauge stop working when kept for sleeping mode more that 15 sec. This research propose a new strategy, road map and conceptual design with different scenarios that aim to overcome the previous disadvantage through generating electrical power through a special downhole turbine utilizing new concept through wells injection and/or production flow rates. The new recommended turbine either to be installed as a part of the completion as permanent or to be run as retrievable. Moreover, turbine has the ability to generate mandatory power to operate downhole devices fitting any sensors. (eg. memory gauge) The new self power turbine create a new strategy for gas, oil and water wells completion to be more advanced with no need for the rig to change the completion, tubing and/or install cables. Theoretically the research succeeded by mean of installing a turbine to generate constant D/C current that could power up any attached memory gauge. This turbine depend on it is design on two main concepts; the first is how to direct the flow toward the blades and the second is how to maximize the vortex effect to maximize velocity and control turbulence, take in consideration hole accessibility for any operation required.
{"title":"Permanent Electric Power Supply for Down Hole Devices in Oil and Gas Wells","authors":"Eng Ammar, Mohamed Nabil, M.Hegazy, Gehad","doi":"10.2118/193037-MS","DOIUrl":"https://doi.org/10.2118/193037-MS","url":null,"abstract":"\u0000 All present time, most of downhole electrical devices operate either retrievable \"rechargeable batteries\" or permanent electric or fiber cable extend from surface till the bottom associated with high risk and high cost operations.\u0000 Commonly both retrievable and permanent devices have advantage such as live data and easy communication. However, the disadvantages are temperature limitation, high cost, high risk, and restrictions moreover not suit many other completion scenarios and wells completion types.\u0000 Most of memory gauges could read with 5 sec rate up to 43 days in temperature range 150 C, and it will reduce to 18 days when temperature increase up to 200 C. even increasing the time by reducing number of decimals for the recorded values. However, memory gauge stop working when kept for sleeping mode more that 15 sec.\u0000 This research propose a new strategy, road map and conceptual design with different scenarios that aim to overcome the previous disadvantage through generating electrical power through a special downhole turbine utilizing new concept through wells injection and/or production flow rates.\u0000 The new recommended turbine either to be installed as a part of the completion as permanent or to be run as retrievable. Moreover, turbine has the ability to generate mandatory power to operate downhole devices fitting any sensors. (eg. memory gauge)\u0000 The new self power turbine create a new strategy for gas, oil and water wells completion to be more advanced with no need for the rig to change the completion, tubing and/or install cables.\u0000 Theoretically the research succeeded by mean of installing a turbine to generate constant D/C current that could power up any attached memory gauge. This turbine depend on it is design on two main concepts; the first is how to direct the flow toward the blades and the second is how to maximize the vortex effect to maximize velocity and control turbulence, take in consideration hole accessibility for any operation required.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89769643","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}
Commercial use of drones – inspection drones to be specific – in Oil & Gas sector has been on the rise since around 2010. Leading Multinationals and some North American companies managing petroleum assets are among the first to tailor their inspection procedures incorporating the use of inspection drones. This inevitable switch is based on a rationale – safety of inspection personnel including ease of access to hazardous locations. Other factors that incentivize the use of inspection drones include time savings, lower costs, early warnings, improved data collection and sometimes the only viable option to get first hand information about an emergency event. Petroleum industry assets are high-value-long-life assets which are built to process / handle hazardous fluids. Operation & maintenance of these assets is a carefully regulated activity under the dictates of regulatory guidance, codes & standards. These compliance obligations burden the operators of these assets to optimize operations based on reliability centered maintenance philosophy. Consequently, inspection drones have in a very short span of time (5 – 10 years), have succeeded in proving their utility to support the operators and asset managers in meeting responsibilities related to the following: A-1. Operational ResponsibilityA-2. Corporate & Social Responsibility (CSR)A-3. Environmental ResponsibilityA-4. Security Responsibility This paper is an effort to collect and present data signifying the utility of inspection drones for asset management as well as optimized operations – onshore operations related to exploration and production as well as oil transportation.
{"title":"Eye in the Sky: How the Rise of Drones will Transfrom the Oil & Gas Industry","authors":"Noorafkan Amir, Mohamed Saeed Al Marar","doi":"10.2118/193211-MS","DOIUrl":"https://doi.org/10.2118/193211-MS","url":null,"abstract":"\u0000 Commercial use of drones – inspection drones to be specific – in Oil & Gas sector has been on the rise since around 2010. Leading Multinationals and some North American companies managing petroleum assets are among the first to tailor their inspection procedures incorporating the use of inspection drones. This inevitable switch is based on a rationale – safety of inspection personnel including ease of access to hazardous locations. Other factors that incentivize the use of inspection drones include time savings, lower costs, early warnings, improved data collection and sometimes the only viable option to get first hand information about an emergency event.\u0000 Petroleum industry assets are high-value-long-life assets which are built to process / handle hazardous fluids. Operation & maintenance of these assets is a carefully regulated activity under the dictates of regulatory guidance, codes & standards. These compliance obligations burden the operators of these assets to optimize operations based on reliability centered maintenance philosophy. Consequently, inspection drones have in a very short span of time (5 – 10 years), have succeeded in proving their utility to support the operators and asset managers in meeting responsibilities related to the following: A-1. Operational ResponsibilityA-2. Corporate & Social Responsibility (CSR)A-3. Environmental ResponsibilityA-4. Security Responsibility\u0000 This paper is an effort to collect and present data signifying the utility of inspection drones for asset management as well as optimized operations – onshore operations related to exploration and production as well as oil transportation.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88890484","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}
In congested districts of offshore Oil & Gas Industry, merchant ship traffic, offshore operations or fishing activity may interfere with pipelines in service, which rest exposed on the seabed. Despite the shortcomings of existing technology and knowledge, operators' concerns still emerge after yearly surveys that show new pipe damages from external mechanical interference, not to mention a few ruptures occurred in the last decade due to anchor hooking! Therefore, a question arises: do we know enough about the potential threats to offshore pipelines from external, particularly anchor, interference? The scope of this paper is to outline the rationale of pipeline protection works, both at design stage and in service, with focus on open issues influencing decisions on how and due time to intervene across busy offshore districts. In shallow waters and brown fields, e.g. in the Arabian Gulf and Gulf of Mexico, the consequences, not only economic but also safety wise, of a severe interference, might be relevant. The shallower the water depth and busier the area, the more stringent the safety targets. Sometimes, even having met acceptance criteria, backed by competent engineering modelling and use of state-of-the-art tools, field evidences from early operation may lead to rethink of purpose protection works, to be implemented with minimum impact on field operations. Marine pipeline damage prevention and awareness, from both vessel and field operators, is often a unique way to limit risks and unplanned interruptions.
{"title":"Protecting Offshore Pipelines from External Interference: Dropped and Dragged Anchors.","authors":"R. Bruschi, L. Bartolini","doi":"10.2118/193158-MS","DOIUrl":"https://doi.org/10.2118/193158-MS","url":null,"abstract":"\u0000 In congested districts of offshore Oil & Gas Industry, merchant ship traffic, offshore operations or fishing activity may interfere with pipelines in service, which rest exposed on the seabed. Despite the shortcomings of existing technology and knowledge, operators' concerns still emerge after yearly surveys that show new pipe damages from external mechanical interference, not to mention a few ruptures occurred in the last decade due to anchor hooking! Therefore, a question arises: do we know enough about the potential threats to offshore pipelines from external, particularly anchor, interference? The scope of this paper is to outline the rationale of pipeline protection works, both at design stage and in service, with focus on open issues influencing decisions on how and due time to intervene across busy offshore districts. In shallow waters and brown fields, e.g. in the Arabian Gulf and Gulf of Mexico, the consequences, not only economic but also safety wise, of a severe interference, might be relevant. The shallower the water depth and busier the area, the more stringent the safety targets. Sometimes, even having met acceptance criteria, backed by competent engineering modelling and use of state-of-the-art tools, field evidences from early operation may lead to rethink of purpose protection works, to be implemented with minimum impact on field operations. Marine pipeline damage prevention and awareness, from both vessel and field operators, is often a unique way to limit risks and unplanned interruptions.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"116 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89302202","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. Goraya, Rajeev Nair, A. Al-Neaimi, A. Alfelasi, Franciscus Johannes Kleef, Bader Al-Dhafari, M. El-Sayed, Fazeel Akram, I. Al-Hosani
During a routine tower maintenance visit, gas bubbles were observed at sea bed. The challenge now was to identify the source of the gas leak and identify areas where gas had accumulated. The observed gas seep, escaped from the seabed to the water column and was in the vicinity of the TWR-2 platform as confirmed during a diving survey. A geophysical survey was initiated to understand if gas had accumulated in the subsurface and whether it was safe to approach the site with a rig to kill the well.
{"title":"Innovative Geophysical Hazard Survey for Jack-Up Rig Approach and Operating in Hazardous Area of Shallow Seabed Due to Gas Pockets or Entrapped Gas and Tower Integrity Update and Conclusion. A Case Study","authors":"Y. Goraya, Rajeev Nair, A. Al-Neaimi, A. Alfelasi, Franciscus Johannes Kleef, Bader Al-Dhafari, M. El-Sayed, Fazeel Akram, I. Al-Hosani","doi":"10.2118/193091-MS","DOIUrl":"https://doi.org/10.2118/193091-MS","url":null,"abstract":"\u0000 During a routine tower maintenance visit, gas bubbles were observed at sea bed. The challenge now was to identify the source of the gas leak and identify areas where gas had accumulated. The observed gas seep, escaped from the seabed to the water column and was in the vicinity of the TWR-2 platform as confirmed during a diving survey. A geophysical survey was initiated to understand if gas had accumulated in the subsurface and whether it was safe to approach the site with a rig to kill the well.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"217 6","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91421722","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}
Inform and educate oil and gas pipe engineers of the safe and reliable solutions to pipe motion at high pressures. Expansion joints for Axial and Offset technology pipe systems. Ball joint designs in the offset and scissor installations for Offshore, Onshore, Production, Development and Distribution pipe systems. Axial and Offset Pipe system technology and what are the advantages? How are expansion joints installed? What is a ball joint and how do they work? How to model expansion joints in a pipe stress program? Ball joints are not new. Barco Ball joints have been around since 1908. The designs were developed to ensure steam could reach the front of a train from the boiler in the back across each car connection. The Steam piping made the passenger cars warm and comfortable. Today, Ball Joints provide a method of absorbing pipe movement for applications ranging to high pressures, steam and hot water pipe expansion, tank and building settlement, seismic isolation, wave motion compensation on oil platforms, barges, FPSO and drilling ships, solar panel movement, oil well riser expansion and safety relief valve escape piping.
{"title":"Piping Motion Solutions-Ball Joint Technology","authors":"Arlene Chase","doi":"10.2118/192676-MS","DOIUrl":"https://doi.org/10.2118/192676-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Inform and educate oil and gas pipe engineers of the safe and reliable solutions to pipe motion at high pressures. Expansion joints for Axial and Offset technology pipe systems. Ball joint designs in the offset and scissor installations for Offshore, Onshore, Production, Development and Distribution pipe systems.\u0000 Axial and Offset Pipe system technology and what are the advantages? How are expansion joints installed? What is a ball joint and how do they work? How to model expansion joints in a pipe stress program?\u0000 Ball joints are not new. Barco Ball joints have been around since 1908. The designs were developed to ensure steam could reach the front of a train from the boiler in the back across each car connection. The Steam piping made the passenger cars warm and comfortable. Today, Ball Joints provide a method of absorbing pipe movement for applications ranging to high pressures, steam and hot water pipe expansion, tank and building settlement, seismic isolation, wave motion compensation on oil platforms, barges, FPSO and drilling ships, solar panel movement, oil well riser expansion and safety relief valve escape piping.\u0000","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"14 11","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91468293","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}
Ibrahim Khan, Yasser Al Wahedi, Vaithilingam Balasubramanian, M. Tsapatsis, Frank Geuzobroek, Adel Saif Al Nasr, Khadija Al Daghar
This paper explains the process work flow steps starting from the proof of concept of a new research technology up to the field demonstration considering a live example. We discuss the stages that are employed in ADNOC R&TD technology management process in assessing proposals, supervising projects progress, steering projects towards technology maturity. The example under study pertains to a research project which was awarded to Khalifa University (KU). The project attempts at solving high SO2 emissions from old Sulfur Recovery Units (SRUs) in ADNOC Gas Processing. The subject project is research work involving development of a mixed metal oxide, highly selective regenerable adsorbent possessing high adsorption capacity of 6 to 8 mmol/g. We follow the progress of the new technology via the various steps of ADNOC R&D technology management process.
{"title":"Technology Demonstration Journey in ADNOC R&D – A Case Study","authors":"Ibrahim Khan, Yasser Al Wahedi, Vaithilingam Balasubramanian, M. Tsapatsis, Frank Geuzobroek, Adel Saif Al Nasr, Khadija Al Daghar","doi":"10.2118/192633-MS","DOIUrl":"https://doi.org/10.2118/192633-MS","url":null,"abstract":"\u0000 This paper explains the process work flow steps starting from the proof of concept of a new research technology up to the field demonstration considering a live example. We discuss the stages that are employed in ADNOC R&TD technology management process in assessing proposals, supervising projects progress, steering projects towards technology maturity. The example under study pertains to a research project which was awarded to Khalifa University (KU). The project attempts at solving high SO2 emissions from old Sulfur Recovery Units (SRUs) in ADNOC Gas Processing. The subject project is research work involving development of a mixed metal oxide, highly selective regenerable adsorbent possessing high adsorption capacity of 6 to 8 mmol/g. We follow the progress of the new technology via the various steps of ADNOC R&D technology management process.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"34 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90821874","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}
Carbon capture and Storage is one of the major pathways to reduce carbon dioxide emission. Over the years, the success of this technology has been relatively limited. Reasons for this include lack of acceptance of storage, but also a lack of economic feasibility. In many cases, projects need to be funded through subsidies or are justified on the basis of use for enhanced oil recovery. Meanwhile an enormous effort has been placed into lowering the cost of capture. Many R&D programs have set the target to reduce cost from typically 50 $/ton to 25 $/ton, while even now this kind of reductions have not been realized, to the contrary there has been an increase in reported cost. This paper addresses the background of the situation. It gives a literature overview of different technologies and the associated cost. A cost analysis is made of the different components in a CO2 capture plant. Comparison is made for the different technologies for post, pre- and oxy-combustion. The reasons for the high cost is analyzed and it is shown that no silver bullets exist. Several smart technologies are currently in development and the latest insights are given in how these technologies can reduce cost. A few studies are given that show why these technologies could not fulfill the initial expectations. The results show that there is a tendency that advantages of technology solutions are often off-set by disadvantages that are not foreseen at the early Research stages, often because the new systems are more complicated than the state-of-the-art. This includes engineering cost for mitigate these dis advantages. An example is the use of smart solvents with phase change involved. This process may lead to lower OPEX due to lower energy consumption, but cost is increased by the higher cost for doing the separation or for keeping the solvents from leaving the solvent.
{"title":"Low Cost CO2 Capture: Dream or Reality?","authors":"A. S. E. Nasr, F. Geuzebroek, Prachi Singh","doi":"10.2118/192726-MS","DOIUrl":"https://doi.org/10.2118/192726-MS","url":null,"abstract":"Carbon capture and Storage is one of the major pathways to reduce carbon dioxide emission. Over the years, the success of this technology has been relatively limited. Reasons for this include lack of acceptance of storage, but also a lack of economic feasibility. In many cases, projects need to be funded through subsidies or are justified on the basis of use for enhanced oil recovery. Meanwhile an enormous effort has been placed into lowering the cost of capture. Many R&D programs have set the target to reduce cost from typically 50 $/ton to 25 $/ton, while even now this kind of reductions have not been realized, to the contrary there has been an increase in reported cost. This paper addresses the background of the situation. It gives a literature overview of different technologies and the associated cost. A cost analysis is made of the different components in a CO2 capture plant. Comparison is made for the different technologies for post, pre- and oxy-combustion. The reasons for the high cost is analyzed and it is shown that no silver bullets exist. Several smart technologies are currently in development and the latest insights are given in how these technologies can reduce cost. A few studies are given that show why these technologies could not fulfill the initial expectations. The results show that there is a tendency that advantages of technology solutions are often off-set by disadvantages that are not foreseen at the early Research stages, often because the new systems are more complicated than the state-of-the-art. This includes engineering cost for mitigate these dis advantages. An example is the use of smart solvents with phase change involved. This process may lead to lower OPEX due to lower energy consumption, but cost is increased by the higher cost for doing the separation or for keeping the solvents from leaving the solvent.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77216551","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}
Carbon dioxide (CO2) management is vital for ensuring the economic and environment viability for monetization of high CO2 gas field. Apart from the great technical challenge in separating high concentration of CO2 in gas field economically, the management of separated CO2 is a fine balance between the sink-in value by sequestration and creation of value via conversion to product, constrained by the thermodynamic challenge in breaking the stable CO2 molecule. Conversion to methane is one the exploratory idea due to ease of integration to current product line-up of PETRONAS. Catalytic conversion of CO2 to methane are reported here over various supported nickel base catalyst, namely ZrO2, La2O3, and Al2O3 at temperature ranging from 300 to 400°C under atmospheric pressure. The catalysts with fixed Ni loadings were prepared by wet impregnation technique, characterized and their performances were evaluated in a parallel reactor under Sabatier-based CO2 conversion. Reaction temperature and GHSV were taken into account as two important parameters with fixed H2/CO2 molar ratio. Experimental results indicate that among all catalysts, Ni/Al2O3 give the highest CO2 conversion of 74% and high CH4 selectivity of 99% at temperature of 380°C and GHSV 10000 h-1. This asserted Ni supported on Al2O3 as a potential catalyst for CO2 conversion and promising methanation performance over a low cost catalyst.
{"title":"Feasibility Study of Carbon Dioxide Methanation: Assessment of Various Supported Nickel Catalyst","authors":"N. Berahim, A. Seman, M. G. M. Noh","doi":"10.2118/193294-MS","DOIUrl":"https://doi.org/10.2118/193294-MS","url":null,"abstract":"\u0000 Carbon dioxide (CO2) management is vital for ensuring the economic and environment viability for monetization of high CO2 gas field. Apart from the great technical challenge in separating high concentration of CO2 in gas field economically, the management of separated CO2 is a fine balance between the sink-in value by sequestration and creation of value via conversion to product, constrained by the thermodynamic challenge in breaking the stable CO2 molecule. Conversion to methane is one the exploratory idea due to ease of integration to current product line-up of PETRONAS. Catalytic conversion of CO2 to methane are reported here over various supported nickel base catalyst, namely ZrO2, La2O3, and Al2O3 at temperature ranging from 300 to 400°C under atmospheric pressure. The catalysts with fixed Ni loadings were prepared by wet impregnation technique, characterized and their performances were evaluated in a parallel reactor under Sabatier-based CO2 conversion. Reaction temperature and GHSV were taken into account as two important parameters with fixed H2/CO2 molar ratio. Experimental results indicate that among all catalysts, Ni/Al2O3 give the highest CO2 conversion of 74% and high CH4 selectivity of 99% at temperature of 380°C and GHSV 10000 h-1. This asserted Ni supported on Al2O3 as a potential catalyst for CO2 conversion and promising methanation performance over a low cost catalyst.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80950504","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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