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{"title":"OPTC2021 Front Matter","authors":"","doi":"10.1115/optc2021-fm1","DOIUrl":"https://doi.org/10.1115/optc2021-fm1","url":null,"abstract":"\u0000 The front matter for this proceedings is available by clicking on the PDF icon.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"133 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131720513","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 view of the vibration failure of drilling string system in ultra-high temperature and high pressure (ultra-HPHT) curved wells, an axial-lateral-torsion coupling (ALTC) nonlinear vibration model of drilling string system was established using energy method and Hamiltonian principle, in which, the influence of wellbore trajectory change, wellbore constraint, interaction between bit and rock and ultra-HPHT of wellbore on elastic modulus and viscosity of drilling fluid were taken into account. The finite element method (FEM) is used to realize the numerical solution of the nonlinear vibration model. The correctness and validity of the ALTC nonlinear vibration model was verified by comparing the measured data of four ultra-HPHT wells with the theoretical calculation results of the proposed model. The research results provide a theoretically sound guidance for designing and practically sound approach for effectively improving rate of penetration (ROP) and the service life of drilling string in ultra-HPHT curved wells.
{"title":"Investigation on Axial-Lateral-Torsion Nonlinear Coupling Vibration Model of Drilling String in Ultra-HPHT Curved Wells","authors":"Xiaoqiang Guo, J. Liu, Jianxun Wang, Haiyan Zhu","doi":"10.1115/optc2021-67533","DOIUrl":"https://doi.org/10.1115/optc2021-67533","url":null,"abstract":"\u0000 In view of the vibration failure of drilling string system in ultra-high temperature and high pressure (ultra-HPHT) curved wells, an axial-lateral-torsion coupling (ALTC) nonlinear vibration model of drilling string system was established using energy method and Hamiltonian principle, in which, the influence of wellbore trajectory change, wellbore constraint, interaction between bit and rock and ultra-HPHT of wellbore on elastic modulus and viscosity of drilling fluid were taken into account. The finite element method (FEM) is used to realize the numerical solution of the nonlinear vibration model. The correctness and validity of the ALTC nonlinear vibration model was verified by comparing the measured data of four ultra-HPHT wells with the theoretical calculation results of the proposed model. The research results provide a theoretically sound guidance for designing and practically sound approach for effectively improving rate of penetration (ROP) and the service life of drilling string in ultra-HPHT curved wells.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115288854","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}
Andrea Mantini, Steve Goldstein, Colleen Rimlinger
Key changes have triggered the push for frac fleet innovation. With environmental regulation efforts to cut down on emissions increasing, more and more companies are transitioning to the use of electric fleet equipment. Electric fleets use natural gas, which burns cleaner than diesel fuel. Our study found the gas turbine outperformed Tier 4 dual fuel blend (DF) reciprocating engines and demonstrated a step change improvement in both direct and indirect emissions reductions over the 20+ year lifecycle of the Baker Hughes LM2500 in Permian and Williston Basins’ field operating conditions. An even greater impact to direct GHG (as CO2 equivalent) emissions reduction came to light when the potential to reduce flaring of associated gas was considered. Gas turbines have been proven to have the best-in-class emissions for powering pressure pumping fleets and lead the industry on fuel cost savings and in achieving commitments to reduce carbon emissions in places like the Permian Basin in Texas and remote areas across the world. Though, recent industry studies abominably suggest that Tier 4 diesel and Tier 4 dual fuel (DF) engine technologies offer an alternative with emissions benefits in comparison to current gas turbine offerings this study demonstrate the contrary.
{"title":"Decarbonization Advancements in Pressure Pumping With Gas Turbines","authors":"Andrea Mantini, Steve Goldstein, Colleen Rimlinger","doi":"10.1115/optc2021-66788","DOIUrl":"https://doi.org/10.1115/optc2021-66788","url":null,"abstract":"\u0000 Key changes have triggered the push for frac fleet innovation. With environmental regulation efforts to cut down on emissions increasing, more and more companies are transitioning to the use of electric fleet equipment. Electric fleets use natural gas, which burns cleaner than diesel fuel.\u0000 Our study found the gas turbine outperformed Tier 4 dual fuel blend (DF) reciprocating engines and demonstrated a step change improvement in both direct and indirect emissions reductions over the 20+ year lifecycle of the Baker Hughes LM2500 in Permian and Williston Basins’ field operating conditions. An even greater impact to direct GHG (as CO2 equivalent) emissions reduction came to light when the potential to reduce flaring of associated gas was considered.\u0000 Gas turbines have been proven to have the best-in-class emissions for powering pressure pumping fleets and lead the industry on fuel cost savings and in achieving commitments to reduce carbon emissions in places like the Permian Basin in Texas and remote areas across the world. Though, recent industry studies abominably suggest that Tier 4 diesel and Tier 4 dual fuel (DF) engine technologies offer an alternative with emissions benefits in comparison to current gas turbine offerings this study demonstrate the contrary.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117122445","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}
The application of mega complex projects in the heavy industrial sector have been growing globally for the last ten years. Given there is growth of mega complex projects, the failure rate of these types of projects has also increased. According the EY (who have analyzed 500 completed mega projects from the previous five years): “Of the projects analyzed, 60% experienced schedule delays, and 38% had cost overruns.” Based on research performed by McKinsey & Company, the construction industry needs to change to become more productive and as the industry changes it will look very different five to ten years from now. These changes will only be accelerated by the current COVID-19 pandemic. One solution is the application of smaller standard modular plants or trains that can be designed and constructed quicker and more efficiently. A product-based approach will lead to more of a manufacturing style approach to not only improve productivity but to reduce overall lifecycle costs and schedules and improve overall quality and safety. Further, in times of economic uncertainty, it will reduce the business risk for the project as the business can break the project down into “bite-sized pieces”. Companies will need to be innovative in order to be competitive and have a positive return on investment on their future programs and projects. In the current and future economic environment, an innovative way to execute projects is to utilize a product-based approach. This paper will focus on how to develop a standard modular plant using a product-based approach and provide a case study from a small-scale LNG plant.
{"title":"A Different Way to Execute Project Using a Product-Based Approach","authors":"Cathy Farina","doi":"10.1115/optc2021-66752","DOIUrl":"https://doi.org/10.1115/optc2021-66752","url":null,"abstract":"\u0000 The application of mega complex projects in the heavy industrial sector have been growing globally for the last ten years. Given there is growth of mega complex projects, the failure rate of these types of projects has also increased. According the EY (who have analyzed 500 completed mega projects from the previous five years): “Of the projects analyzed, 60% experienced schedule delays, and 38% had cost overruns.”\u0000 Based on research performed by McKinsey & Company, the construction industry needs to change to become more productive and as the industry changes it will look very different five to ten years from now. These changes will only be accelerated by the current COVID-19 pandemic. One solution is the application of smaller standard modular plants or trains that can be designed and constructed quicker and more efficiently.\u0000 A product-based approach will lead to more of a manufacturing style approach to not only improve productivity but to reduce overall lifecycle costs and schedules and improve overall quality and safety. Further, in times of economic uncertainty, it will reduce the business risk for the project as the business can break the project down into “bite-sized pieces”.\u0000 Companies will need to be innovative in order to be competitive and have a positive return on investment on their future programs and projects. In the current and future economic environment, an innovative way to execute projects is to utilize a product-based approach.\u0000 This paper will focus on how to develop a standard modular plant using a product-based approach and provide a case study from a small-scale LNG plant.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123468632","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}
N. A. Abdul Talip, S. A. Abidin, M. H. Pikri, L. A. Karim, A. W. Zakaria, N. A. Abu Bakar
Methane concentration in the atmosphere is increasing steadily and this increment is driving climate change and continue to rise. Although the estimates of methane emissions are subject to a high degree of uncertainty, the energy sector is still one of the major sources of anthropogenic methane emissions. Focusing on the oil and gas industry, methane is emitted during normal operation, routine maintenance and system disruptions. However, globally more energy will be required in the future. Transitioning to a low carbon future requires an energy player in O&G to start managing methane emissions in the natural gas / liquefied natural gas value chain effectively. Many global methane management coalitions were established with common goals i.e. to reduce global methane emissions and to advance the abatement, recovery and use of methane as a valuable clean energy. One of it is Methane Guiding Principles (MGP) which focuses on priority areas for action across the natural gas supply chain, from production to the final consumer. Signatory members of MGP is to fulfill the expectations of the 5 principles in MGP that includes pursuing an accurate methane emissions quantification across its gas value chain. A baseline study was initiated to measure methane emissions for LNG plant, gas processing and gas transmission facilities, covering both intended and unintended releases. Methane emissions were quantified using a process simulation software that was developed by PETRONAS Group Technical Solutions, called iCON Emission, where the calculations applied in the software are aligned with API compendium, US EPA and IPCC. Methane emissions from unintended releases i.e. LOPC and fugitive leaks were quantified using the actual inputs from LDAR data (%LEL or concentration), stream compo, stream phase, device type and component correction factor to calculate methane emission rate. Meanwhile methane emissions from intended releases e.g. flaring, compressor seals, pneumatic devices, etc, were quantified using metered amount or designed leakage/vent rate. Further works on Fugitive emissions are currently developed by PETRONAS technologist using Inferential Modeling via machine learning approach. This approach is combining First Principle and Data Analytics to make Fugitive Emission as online information and accurate reporting. To provide further assurance to the results, PETRONAS had engaged a 3rd party to validate the results where it was concluded that methane emissions quantification using iCON tool is almost the same level of accuracy with Level 3 of OGMP 2.0 standard. This level of accuracy is at par with the practice of the other O&G peers. Based on the baseline identification & quantification of methane emissions, PETRONAS is able to take necessary mitigating action, operating its asset in a safe and sustainable manner protecting the environment while monetizing the methane emissions from LNG and gas processing facilities with approximate cost saving of RM 1
{"title":"Quantifying Methane Emissions Through Process Simulations Model and Beyond","authors":"N. A. Abdul Talip, S. A. Abidin, M. H. Pikri, L. A. Karim, A. W. Zakaria, N. A. Abu Bakar","doi":"10.1115/optc2021-67334","DOIUrl":"https://doi.org/10.1115/optc2021-67334","url":null,"abstract":"\u0000 Methane concentration in the atmosphere is increasing steadily and this increment is driving climate change and continue to rise. Although the estimates of methane emissions are subject to a high degree of uncertainty, the energy sector is still one of the major sources of anthropogenic methane emissions. Focusing on the oil and gas industry, methane is emitted during normal operation, routine maintenance and system disruptions. However, globally more energy will be required in the future. Transitioning to a low carbon future requires an energy player in O&G to start managing methane emissions in the natural gas / liquefied natural gas value chain effectively.\u0000 Many global methane management coalitions were established with common goals i.e. to reduce global methane emissions and to advance the abatement, recovery and use of methane as a valuable clean energy. One of it is Methane Guiding Principles (MGP) which focuses on priority areas for action across the natural gas supply chain, from production to the final consumer. Signatory members of MGP is to fulfill the expectations of the 5 principles in MGP that includes pursuing an accurate methane emissions quantification across its gas value chain. A baseline study was initiated to measure methane emissions for LNG plant, gas processing and gas transmission facilities, covering both intended and unintended releases. Methane emissions were quantified using a process simulation software that was developed by PETRONAS Group Technical Solutions, called iCON Emission, where the calculations applied in the software are aligned with API compendium, US EPA and IPCC. Methane emissions from unintended releases i.e. LOPC and fugitive leaks were quantified using the actual inputs from LDAR data (%LEL or concentration), stream compo, stream phase, device type and component correction factor to calculate methane emission rate. Meanwhile methane emissions from intended releases e.g. flaring, compressor seals, pneumatic devices, etc, were quantified using metered amount or designed leakage/vent rate. Further works on Fugitive emissions are currently developed by PETRONAS technologist using Inferential Modeling via machine learning approach. This approach is combining First Principle and Data Analytics to make Fugitive Emission as online information and accurate reporting.\u0000 To provide further assurance to the results, PETRONAS had engaged a 3rd party to validate the results where it was concluded that methane emissions quantification using iCON tool is almost the same level of accuracy with Level 3 of OGMP 2.0 standard. This level of accuracy is at par with the practice of the other O&G peers. Based on the baseline identification & quantification of methane emissions, PETRONAS is able to take necessary mitigating action, operating its asset in a safe and sustainable manner protecting the environment while monetizing the methane emissions from LNG and gas processing facilities with approximate cost saving of RM 1","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"225 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115277388","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. Lagutchik, Martha Ramos-Gomez, Paul Martin, Terry Kennon
Technology qualification is a vital process for de-risking new technologies. This paper provides an overview of a recent technology qualification for a system which converts the normally burned and wasted energy in flare gas into a usable fuel for various applications (flare-to-fuel), thereby reducing the need for other high emissions fuels and providing decarbonization benefits to the end user and the environment. The scope of the qualification process followed a risk-based approach that included the review of technical documents, a technical workshop to identify novel technology aspects and potential threats, and a list of mitigation actions summarized in a Technology Qualification Plan. After successful completion of this first phase of the technology qualification process, according to DNV-RP-A203 [1], DNV issued a Statement of Endorsement of the Qualification Plan.
技术鉴定是降低新技术风险的重要环节。本文概述了一种系统的最新技术鉴定，该系统将火炬气中通常燃烧和浪费的能量转化为各种应用的可用燃料(火炬转燃料)，从而减少了对其他高排放燃料的需求，并为最终用户和环境提供脱碳效益。鉴定过程的范围采用基于风险的方法，其中包括审查技术文件、举办技术讲习班以确定新技术方面和潜在威胁，以及在技术鉴定计划中总结的缓解行动清单。根据DNV- rp - a203标准，在成功完成第一阶段的技术鉴定过程后，DNV发布了一份认可鉴定计划的声明。
{"title":"Maximizing Efficiencies and De-Risking a Flare-to-Fuel Technology","authors":"S. Lagutchik, Martha Ramos-Gomez, Paul Martin, Terry Kennon","doi":"10.1115/optc2021-67444","DOIUrl":"https://doi.org/10.1115/optc2021-67444","url":null,"abstract":"\u0000 Technology qualification is a vital process for de-risking new technologies. This paper provides an overview of a recent technology qualification for a system which converts the normally burned and wasted energy in flare gas into a usable fuel for various applications (flare-to-fuel), thereby reducing the need for other high emissions fuels and providing decarbonization benefits to the end user and the environment. The scope of the qualification process followed a risk-based approach that included the review of technical documents, a technical workshop to identify novel technology aspects and potential threats, and a list of mitigation actions summarized in a Technology Qualification Plan. After successful completion of this first phase of the technology qualification process, according to DNV-RP-A203 [1], DNV issued a Statement of Endorsement of the Qualification Plan.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133908323","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}
Terminals are an integral part of transmission pipelines that can operate in different modes. The two most common modes are single injection and single delivery. Because pressure waves generated after accidental valve closures, pump trips, or others can travel many miles in a few seconds, it is a current practice to simulate the whole mainline to the next pump station, upstream or downstream, due to the lack of a standard method to identify boundaries. This paper proposes a method to define the minimum modeling boundary. This boundary is especially useful when the available data is limited, when multiple suppliers / pipeline owners are connected to a terminal, when advanced simulation software or powerful computers are not available, or when the goal is to avoid unnecessary, complex labor-intensive simulations. The technique consists of identifying a boundary located far enough in the mainline so that pressure waves do not interfere with the development of pressure surges after transient events in the facility piping or in a segment of a pipeline that has the weakest pipe. This straightforward method is supported by concepts published by well-known authorities in the transient hydraulics field and tested with available pipeline simulation software. After reading this paper, the reader will be able to answer these questions: • How much data do I need? • How many permutations? • What info is critical for this method? • Where is the boundary? • What causes a wrong selection? In summary, the hydraulic engineer will be able to shorten the current boundary to small fractions: up to 1/25 in the case of injection facilities and up to 2/25 in the case of delivery facilities. As well, readers will confirm that the hydraulic conditions in the mainlines beyond these boundaries don’t have any effect on the facilities’ piping due to transient events such as accidental valve closures or pumps trips, the most common initiators of large pressure surges.
{"title":"Boundaries Definition for Modeling Transients in Oil Terminals","authors":"Wilfredo Vargas Molina","doi":"10.1115/optc2021-66516","DOIUrl":"https://doi.org/10.1115/optc2021-66516","url":null,"abstract":"\u0000 Terminals are an integral part of transmission pipelines that can operate in different modes. The two most common modes are single injection and single delivery. Because pressure waves generated after accidental valve closures, pump trips, or others can travel many miles in a few seconds, it is a current practice to simulate the whole mainline to the next pump station, upstream or downstream, due to the lack of a standard method to identify boundaries.\u0000 This paper proposes a method to define the minimum modeling boundary. This boundary is especially useful when the available data is limited, when multiple suppliers / pipeline owners are connected to a terminal, when advanced simulation software or powerful computers are not available, or when the goal is to avoid unnecessary, complex labor-intensive simulations.\u0000 The technique consists of identifying a boundary located far enough in the mainline so that pressure waves do not interfere with the development of pressure surges after transient events in the facility piping or in a segment of a pipeline that has the weakest pipe.\u0000 This straightforward method is supported by concepts published by well-known authorities in the transient hydraulics field and tested with available pipeline simulation software.\u0000 After reading this paper, the reader will be able to answer these questions:\u0000 • How much data do I need?\u0000 • How many permutations?\u0000 • What info is critical for this method?\u0000 • Where is the boundary?\u0000 • What causes a wrong selection?\u0000 In summary, the hydraulic engineer will be able to shorten the current boundary to small fractions: up to 1/25 in the case of injection facilities and up to 2/25 in the case of delivery facilities. As well, readers will confirm that the hydraulic conditions in the mainlines beyond these boundaries don’t have any effect on the facilities’ piping due to transient events such as accidental valve closures or pumps trips, the most common initiators of large pressure surges.","PeriodicalId":443319,"journal":{"name":"ASME 2021 Onshore Petroleum Technology Conference","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-09-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129011252","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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