Peninsular Malaysia is made up of three fundamental stratigraphic belts; the Central Belt, the Eastern Belt, and the Western Belt with little data on their shale lithologies. The Belata Formation is situated in the Western Belt and is at the southernmost part of Tanjung Malim in the Perak State bordering the Selangor State. Belata Formation falls in between the Terolak and the Karak formations to the north and south respectively. Six Carboniferous shale outcrops were discovered during fieldwork. Outcrop description, sample collection, and laboratory studies were conducted on the Belata Formation. The outcrops include shales that range from black to grey. For laboratory investigation, twenty-two samples were obtained from the shale outcrops. Total organic carbon (TOC) analyses carried out on the samples revealed an average of 3.4 wt. %. The black color is possibly introduced in these shales because of organic matter incorporated in the sediments. Hence, these shales tentatively could be regarded as potential shale gas exploration targets in the Peninsular. However, the effect of the regional rnetarnorphisrn which affected the Sibumasu Terrane should be considered even though shales are not affected by contact metamorphism due to their distance further away from the granitic intrusions.
{"title":"Geological Field Characteristic of the Black Shales in the Belata Formation, Peninsular Malaysia","authors":"E. B. Owusu, H. Tsegab, R. Abubakar","doi":"10.4043/31444-ms","DOIUrl":"https://doi.org/10.4043/31444-ms","url":null,"abstract":"\u0000 Peninsular Malaysia is made up of three fundamental stratigraphic belts; the Central Belt, the Eastern Belt, and the Western Belt with little data on their shale lithologies. The Belata Formation is situated in the Western Belt and is at the southernmost part of Tanjung Malim in the Perak State bordering the Selangor State. Belata Formation falls in between the Terolak and the Karak formations to the north and south respectively. Six Carboniferous shale outcrops were discovered during fieldwork. Outcrop description, sample collection, and laboratory studies were conducted on the Belata Formation. The outcrops include shales that range from black to grey. For laboratory investigation, twenty-two samples were obtained from the shale outcrops. Total organic carbon (TOC) analyses carried out on the samples revealed an average of 3.4 wt. %. The black color is possibly introduced in these shales because of organic matter incorporated in the sediments. Hence, these shales tentatively could be regarded as potential shale gas exploration targets in the Peninsular. However, the effect of the regional rnetarnorphisrn which affected the Sibumasu Terrane should be considered even though shales are not affected by contact metamorphism due to their distance further away from the granitic intrusions.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73217531","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 urgency to mitigate climate change is increasing the rate of transformation in energy supply systems towards a low carbon future to ensure global temperature rise is limited to 1.5 Deg. Existing offshore energy technologies were examined through the lens of cluster benefits. Offshore renewable technologies considered were Offshore Wind, Floating Solar, Wave Energy, Tidal Energy and Offshore Thermal Energy (OTEC). The theory of underpinning of clusters, evolution, benefits, and challenges were reviewed. To corroborate the literature review, a pilot survey was sent to participants in industry which commented and highlighted their awareness of certain available technologies. The perceived benefits of clustering included the ability to achieve economies of scale whilst challenges remained around permitting and obtaining social licences. Based on the literature review and survey, a theoretical framework has been proposed to evaluate offshore energy cluster benefits. There is scope to further this research with a larger sample size and diversity of participants to strengthen the framework. It was noted that geospatial hard constraints and policies could be important framing factors for cluster formation in countries of interest. Country specific cluster examination would bring more specificity, depth and application and should be an area of future research.
{"title":"Evaluation of Offshore Renewable Energy for Cluster Benefits","authors":"S. C. Rao","doi":"10.4043/31544-ms","DOIUrl":"https://doi.org/10.4043/31544-ms","url":null,"abstract":"\u0000 The urgency to mitigate climate change is increasing the rate of transformation in energy supply systems towards a low carbon future to ensure global temperature rise is limited to 1.5 Deg. Existing offshore energy technologies were examined through the lens of cluster benefits. Offshore renewable technologies considered were Offshore Wind, Floating Solar, Wave Energy, Tidal Energy and Offshore Thermal Energy (OTEC). The theory of underpinning of clusters, evolution, benefits, and challenges were reviewed. To corroborate the literature review, a pilot survey was sent to participants in industry which commented and highlighted their awareness of certain available technologies. The perceived benefits of clustering included the ability to achieve economies of scale whilst challenges remained around permitting and obtaining social licences. Based on the literature review and survey, a theoretical framework has been proposed to evaluate offshore energy cluster benefits. There is scope to further this research with a larger sample size and diversity of participants to strengthen the framework. It was noted that geospatial hard constraints and policies could be important framing factors for cluster formation in countries of interest. Country specific cluster examination would bring more specificity, depth and application and should be an area of future research.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75168176","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Alekseev, L. Samigullin, M. Zimoglyad, V. Nagovitsyn, V. Bolshakov, A.Y. Bydzan, Vishwajit Upadhye, D. Vasechkin
One of the largest oil fields on the Yamal Peninsula, the Field NP is characterised by complex geological settings. Massive gas caps pose significant complications to the extraction of large oil reserves occurring immediately below them. In such conditions, new approaches are required to achieve economically viable production. This involves well construction based on a fundamentally new configuration and the use of new technologies. When drilling wells that penetrate more than one target reservoir, the legislation requires performance monitoring and separate production allocation for each reservoir. The article dwells on the first case of separate production allocation in a multilateral well completed with the TAML-1 solution. The well penetrates two reservoirs with different porosity and permeability, using the dynamic quantum PLT technology. The well was drilled taking into account the properties of the impermeable top of one of the reservoirs.
{"title":"Increasing the Accuracy of Production Allocation from Each Reservoir: Integrating TAML-1 Well Construction Technology and the Dynamic Quantum PLT Method in the Field NP","authors":"A. Alekseev, L. Samigullin, M. Zimoglyad, V. Nagovitsyn, V. Bolshakov, A.Y. Bydzan, Vishwajit Upadhye, D. Vasechkin","doi":"10.4043/31652-ms","DOIUrl":"https://doi.org/10.4043/31652-ms","url":null,"abstract":"\u0000 One of the largest oil fields on the Yamal Peninsula, the Field NP is characterised by complex geological settings. Massive gas caps pose significant complications to the extraction of large oil reserves occurring immediately below them. In such conditions, new approaches are required to achieve economically viable production. This involves well construction based on a fundamentally new configuration and the use of new technologies.\u0000 When drilling wells that penetrate more than one target reservoir, the legislation requires performance monitoring and separate production allocation for each reservoir.\u0000 The article dwells on the first case of separate production allocation in a multilateral well completed with the TAML-1 solution. The well penetrates two reservoirs with different porosity and permeability, using the dynamic quantum PLT technology. The well was drilled taking into account the properties of the impermeable top of one of the reservoirs.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74743289","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}
Cai Wang, Xishun Zhang, Ruidong Zhao, Junfeng Shi, Hanjun Zhao, Yizhen Sun, C. Xiong, Feng Deng
Intermittent pumping is an effective measure to reduce energy consumption and improve production time rate for tight oil wells with extremely low oil production. However, the intermittent pumping scheme is mainly controlled by manual timing or RTU remote timing in the cloud. The design of intermittent pumping interval lacks reasonable theoretical basis and the control efficiency is relatively low. Therefore, an integrated intelligent intermittent pumping device combining edge optimization analytic and edge control is developed. A closed-loop integrated device containing real-time data acquisition and transmitting module, optimization module and edge control module is realized. The optimization module embeds the pump fullness calculation model and intermittent pumping scheme optimization model. Instead of using dynamometer cards, a deep learning model of transferring power curves to dynamometer cards named PTD (Power to Dynamometer) is established through deep learning in order to lower the oilfield IoT cost. The average single well area error of predicted dynamometer card is less than 3%. To transfer the PTD to untrained new wells, a parallel model is established by parallel connection of PTD and transferring learning model. The parallel model is embedded into the edge computing device to realize the dynamometer card real-time prediction and pump fullness calculation. The calculated data is transmitted to scheme optimization model where a reasonable intermittent pumping scheme can be optimized. Then the optimized pumping scheme is transmitted back to the edge control device to adjust the pumping scheme to realize loop control. This technology was applied to 100 wells in the oilfield, the monthly energy consumption reduced by 30%, and the average pump efficiency increased by about 17%. The application of this technology is insightful to promote the IoT and intelligence of oilfield artificial lifting system.
间歇式抽油是极低产油量致密油井降低能耗、提高生产时间的有效措施。然而，间歇泵送方案主要由手动定时或云中RTU远程定时控制。间歇式抽油间隔的设计缺乏合理的理论依据，控制效率较低。为此，开发了一种边缘优化分析与边缘控制相结合的集成式智能间歇泵装置。实现了包含实时数据采集与传输模块、优化模块和边缘控制模块的闭环集成装置。优化模块中嵌入了泵满度计算模型和间歇泵方案优化模型。为了降低油田物联网成本，通过深度学习建立了将功率曲线转换为功率卡的深度学习模型PTD (power to dynamometer)，而不是使用测功机卡。预测测功卡的平均单井面积误差小于3%。将PTD与迁移学习模型并行连接，建立了将PTD迁移到未训练新井的并行模型。将并行模型嵌入到边缘计算设备中，实现测功卡实时预测和泵满度计算。将计算得到的数据传输到方案优化模型中，从而优化出合理的间歇抽水方案。然后将优化后的抽送方案传回边缘控制装置，对抽送方案进行调整，实现闭环控制。该技术应用于油田100口井，月能耗降低30%，平均泵效率提高17%左右。该技术的应用对推动油田人工举升系统的物联网和智能化具有重要意义。
{"title":"Edge Optimization Analytics and Control: A Integrated Device of Intelligent Intermittent Pumping for Tight Oil Wells","authors":"Cai Wang, Xishun Zhang, Ruidong Zhao, Junfeng Shi, Hanjun Zhao, Yizhen Sun, C. Xiong, Feng Deng","doi":"10.4043/31669-ms","DOIUrl":"https://doi.org/10.4043/31669-ms","url":null,"abstract":"\u0000 Intermittent pumping is an effective measure to reduce energy consumption and improve production time rate for tight oil wells with extremely low oil production. However, the intermittent pumping scheme is mainly controlled by manual timing or RTU remote timing in the cloud. The design of intermittent pumping interval lacks reasonable theoretical basis and the control efficiency is relatively low. Therefore, an integrated intelligent intermittent pumping device combining edge optimization analytic and edge control is developed.\u0000 A closed-loop integrated device containing real-time data acquisition and transmitting module, optimization module and edge control module is realized. The optimization module embeds the pump fullness calculation model and intermittent pumping scheme optimization model. Instead of using dynamometer cards, a deep learning model of transferring power curves to dynamometer cards named PTD (Power to Dynamometer) is established through deep learning in order to lower the oilfield IoT cost. The average single well area error of predicted dynamometer card is less than 3%. To transfer the PTD to untrained new wells, a parallel model is established by parallel connection of PTD and transferring learning model. The parallel model is embedded into the edge computing device to realize the dynamometer card real-time prediction and pump fullness calculation. The calculated data is transmitted to scheme optimization model where a reasonable intermittent pumping scheme can be optimized. Then the optimized pumping scheme is transmitted back to the edge control device to adjust the pumping scheme to realize loop control.\u0000 This technology was applied to 100 wells in the oilfield, the monthly energy consumption reduced by 30%, and the average pump efficiency increased by about 17%. The application of this technology is insightful to promote the IoT and intelligence of oilfield artificial lifting system.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"156 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85000234","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This paper will share a success story of a well-test operation performed on MUFFIN-X, an appraisal well located at the northern part of the Malaysia-Thailand Joint Development Area (MTJDA). The well was drilled in Q4-2020 and penetrated two fault blocks of northern MTJDA to appraise the area for further field development study and proposal. The objective of the test itself is to acquire new data to reduce the subsurface uncertainties and unlock the gas potential from deep formations of the area, which is well known for its multilayer reservoirs, High Pressure-High Temperature (HPHT), and high CO2-H2S content. These conditions are the key challenges to developing the area. To cope with the challenges, Carigali-PTTEPI Operating Company (CPOC) has been using a Tubing-Stem-Test (TST) approach that provides secured wellbore conditions and multiple accessibilities to multiple reservoirs, straightforward operation, and realistic production simulation. The TST of MUFFIN-X was designed to complete each zone within 24-to-36 hours for deliverability and pressure transient tests. The TST performed on MUFFIN-X has successfully unlocked 20 MMscf/d of gas and 5000 bbl/d of oil potentials from the deep formations of the block. The job was completed 16 hours earlier than the design, bringing approximately 40K USD of cost optimization.
{"title":"An Overview of Successful Fit to Purpose Tubing Stem Test Operation on MUFFIN-X Appraisal Well to Unlock Gas Potential of Deep Formation with HPHT & High CO2-H2S Environment in MTJDA, North Malay Basin","authors":"Avidianto Suryo Setiawan, Sippakorn Apiwathanasorn","doi":"10.4043/31590-ms","DOIUrl":"https://doi.org/10.4043/31590-ms","url":null,"abstract":"\u0000 This paper will share a success story of a well-test operation performed on MUFFIN-X, an appraisal well located at the northern part of the Malaysia-Thailand Joint Development Area (MTJDA). The well was drilled in Q4-2020 and penetrated two fault blocks of northern MTJDA to appraise the area for further field development study and proposal. The objective of the test itself is to acquire new data to reduce the subsurface uncertainties and unlock the gas potential from deep formations of the area, which is well known for its multilayer reservoirs, High Pressure-High Temperature (HPHT), and high CO2-H2S content. These conditions are the key challenges to developing the area. To cope with the challenges, Carigali-PTTEPI Operating Company (CPOC) has been using a Tubing-Stem-Test (TST) approach that provides secured wellbore conditions and multiple accessibilities to multiple reservoirs, straightforward operation, and realistic production simulation. The TST of MUFFIN-X was designed to complete each zone within 24-to-36 hours for deliverability and pressure transient tests. The TST performed on MUFFIN-X has successfully unlocked 20 MMscf/d of gas and 5000 bbl/d of oil potentials from the deep formations of the block. The job was completed 16 hours earlier than the design, bringing approximately 40K USD of cost optimization.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"380 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75521875","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}
Abdelateef M. Adam, A. A. Mohamed Ali, Abdelaziz A. Elsadig, A. Ahmed
The urge to design a selection model for a proper artificial lift system is noticeably escalating. It becomes prudent for the operator to consider most, if not all, of the available evaluation and selection methods. The concept behind it is to yield improved production at better conditions than could be expected. The artificial lift includes five methods, and it is very crucial to select the best method considering the field conditions. In this paper, the best artificial lift is selected using multiple criteria decision-making model which is composed of the combination of Technique for Order Preference by the Similarity to Ideal Solution (TOPSIS) and the Analytic Hierarchy Process (AHP). This new user-friendly model undertakes 15 essential technical factors sorted into three sets (well data, reservoir data, and quantitative data) each factor has its own weight in the final selection decision. Furthermore, the Results depicted in bar graph for further illustration. It is important to note that the final decision is entirely based on technical manners. Additional economic evaluation and detailed cost analysis are required when the model results in close outputs between alternatives. Lastly, this integrated model was tested on 12 wells from block-4 and Block-6 in Sudan, inputs were real-time data from initial and status. Successfully, in the end, it yielded its theoretical results.
{"title":"An Intelligent Selection Model for Optimum Artificial Lift Method Using Multiple Criteria Decision-Making Approach","authors":"Abdelateef M. Adam, A. A. Mohamed Ali, Abdelaziz A. Elsadig, A. Ahmed","doi":"10.4043/31482-ms","DOIUrl":"https://doi.org/10.4043/31482-ms","url":null,"abstract":"\u0000 The urge to design a selection model for a proper artificial lift system is noticeably escalating. It becomes prudent for the operator to consider most, if not all, of the available evaluation and selection methods. The concept behind it is to yield improved production at better conditions than could be expected.\u0000 The artificial lift includes five methods, and it is very crucial to select the best method considering the field conditions. In this paper, the best artificial lift is selected using multiple criteria decision-making model which is composed of the combination of Technique for Order Preference by the Similarity to Ideal Solution (TOPSIS) and the Analytic Hierarchy Process (AHP).\u0000 This new user-friendly model undertakes 15 essential technical factors sorted into three sets (well data, reservoir data, and quantitative data) each factor has its own weight in the final selection decision. Furthermore, the Results depicted in bar graph for further illustration. It is important to note that the final decision is entirely based on technical manners. Additional economic evaluation and detailed cost analysis are required when the model results in close outputs between alternatives.\u0000 Lastly, this integrated model was tested on 12 wells from block-4 and Block-6 in Sudan, inputs were real-time data from initial and status. Successfully, in the end, it yielded its theoretical results.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"58 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73365919","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}
Seismic-well tie is a crucial process to correlate subsurface information from well logs and acquired seismic data. Traditionally, a manual seismic-well tie is conducted based on the interpreter's visual pattern recognition, which is subjective, time-consuming, and may lead to unrealistic velocity distortion. This paper presents a new method to automatically tie seismic to well using Dynamic Time Warping (DTW) and Optimal Interpolation (OI), to save man-hour and to obtain a more reliable time-depth relationship. To produce a better tie, we use DTW to seek the appropriate amounts of time stretching and squeezing to match the synthetic and actual seismic. Then, we balance the rigid pattern matching of DTW by using OI to smooth DTW results and constrain changed rock velocity to be within physical bound. The invented technique has been used to tie seismic to six exploration wells in the Gulf of Thailand. The results from the automated method are then compared with the manual method. For all wells, resulting synthetic-seismic correlations from the automated well tie are higher than the manual method by 1.6%-14.9%. Applied time shifts from the automated and manual methods are then compared. Notably, time adjustment correlations between the automated and manual well tie are considerably high, around 72%-85%, suggesting that both methods yield similar outcomes, yet the automated well tie gives a slightly higher match between tied synthetic and observed seismic traces.
{"title":"Automated Seismic-Well Tie Using Dynamic Time Warping and Optimal Interpolation","authors":"W. Promrak, R. Uttareun","doi":"10.4043/31633-ms","DOIUrl":"https://doi.org/10.4043/31633-ms","url":null,"abstract":"\u0000 Seismic-well tie is a crucial process to correlate subsurface information from well logs and acquired seismic data. Traditionally, a manual seismic-well tie is conducted based on the interpreter's visual pattern recognition, which is subjective, time-consuming, and may lead to unrealistic velocity distortion. This paper presents a new method to automatically tie seismic to well using Dynamic Time Warping (DTW) and Optimal Interpolation (OI), to save man-hour and to obtain a more reliable time-depth relationship. To produce a better tie, we use DTW to seek the appropriate amounts of time stretching and squeezing to match the synthetic and actual seismic. Then, we balance the rigid pattern matching of DTW by using OI to smooth DTW results and constrain changed rock velocity to be within physical bound. The invented technique has been used to tie seismic to six exploration wells in the Gulf of Thailand. The results from the automated method are then compared with the manual method. For all wells, resulting synthetic-seismic correlations from the automated well tie are higher than the manual method by 1.6%-14.9%. Applied time shifts from the automated and manual methods are then compared. Notably, time adjustment correlations between the automated and manual well tie are considerably high, around 72%-85%, suggesting that both methods yield similar outcomes, yet the automated well tie gives a slightly higher match between tied synthetic and observed seismic traces.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74442075","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}
Zul Hilmi Lihin, R. Khan, M. I. M. Ishak, Azam A Rahman, Sumana Kar, A. R. Abdul Rahman
Wave-in-deck (WID) loading has been an issue of concern for engineers dealing with the performance of fixed offshore structures. The issue is particularly relevant for reassessment of existing structures due to subsidence or structures designed to older codes and standards, where WID was not considered. WID issues often in costly subsea remediation, impact platform occupancy levels or premature decommissioning critical structures due to safety concerns. The current in-house procedure is a simplified approach and revised to reflect the silhouette method and new industry requirements for the reliability of fixed offshore structures. The revised reassessment process shall enhance the methodology, based on widely accepted industry best practices. The platform model is calibrated based on the measured in-field platform natural frequencies using a structural health monitoring (SHM) system, so that the reliability assessment can be performed on a structural model to validate the effects of the revised wave in deck approach. The revised methodology demonstrates the potential of unlocking structural capacity of offshore structures by removing conservatism normally associated with traditional reliability assessment methods, thus significantly improving the ability to achieve target structural reliability levels in a cost-effective manner. A case study was embarked upon to demonstrate the benefit of the revised methodology for fixed offshore with insufficient air gap due to subsidence. The pilot study revealed significant improvement in ultimate strength of the structure using the revised methodology by more than 10% improvement in reserve capacity. This provides added benefits for increasing inspection intervals and optimizing the maintenance strategy due to risk reduction and avoidance of costly strengthening modification and repair (SMR). The objective of the present paper is to establish an updated methodology to determine wave-in-deck loading for ultimate strength analysis. The scope of work of the study are as follow: Perform a literature review of wave-in-deck assessment best practices, codes and standards. Develop assessment procedure based on international standards and research papers. Perform ultimate strength assessment based on revised methodology on a selected platform. Preparation of assessment methodology and case study report.
{"title":"Revised Methodology for Assessing Fixed Offshore Structures With Wave in Deck Loading","authors":"Zul Hilmi Lihin, R. Khan, M. I. M. Ishak, Azam A Rahman, Sumana Kar, A. R. Abdul Rahman","doi":"10.4043/31594-ms","DOIUrl":"https://doi.org/10.4043/31594-ms","url":null,"abstract":"\u0000 Wave-in-deck (WID) loading has been an issue of concern for engineers dealing with the performance of fixed offshore structures. The issue is particularly relevant for reassessment of existing structures due to subsidence or structures designed to older codes and standards, where WID was not considered. WID issues often in costly subsea remediation, impact platform occupancy levels or premature decommissioning critical structures due to safety concerns.\u0000 The current in-house procedure is a simplified approach and revised to reflect the silhouette method and new industry requirements for the reliability of fixed offshore structures. The revised reassessment process shall enhance the methodology, based on widely accepted industry best practices.\u0000 The platform model is calibrated based on the measured in-field platform natural frequencies using a structural health monitoring (SHM) system, so that the reliability assessment can be performed on a structural model to validate the effects of the revised wave in deck approach. The revised methodology demonstrates the potential of unlocking structural capacity of offshore structures by removing conservatism normally associated with traditional reliability assessment methods, thus significantly improving the ability to achieve target structural reliability levels in a cost-effective manner.\u0000 A case study was embarked upon to demonstrate the benefit of the revised methodology for fixed offshore with insufficient air gap due to subsidence. The pilot study revealed significant improvement in ultimate strength of the structure using the revised methodology by more than 10% improvement in reserve capacity. This provides added benefits for increasing inspection intervals and optimizing the maintenance strategy due to risk reduction and avoidance of costly strengthening modification and repair (SMR).\u0000 The objective of the present paper is to establish an updated methodology to determine wave-in-deck loading for ultimate strength analysis. The scope of work of the study are as follow:\u0000 Perform a literature review of wave-in-deck assessment best practices, codes and standards. Develop assessment procedure based on international standards and research papers. Perform ultimate strength assessment based on revised methodology on a selected platform. Preparation of assessment methodology and case study report.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"100 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76367404","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 development of the scale layers in oil and gas operation results in production losses and equipment instability because of pipeline blockage, energy leak, corrosion acceleration and severe accidents which will impact the safety of production. Among many types of scales, calcium carbonate and calcium sulfate are considered the most frequent, prominent and terrible. On the other hand, cellulose is a class of natural polymers and also contains abundant functional groups including hydroxyl, carboxyl, and amino groups, resulting in good chelation and dispersion effects. They possess good physical and chemical properties, thermal stability, and biodegradability, abundantly available and inexpensive which make them promising compounds for the creation of "green" oil field reagents, including scale inhibitor. In this study, we tested two types of biodegradable polymers named hydroxyethyl cellulose (HEC) and carboxymethyl cellulose (CMC) for application as calcium carbonate and mixed carbonate and sulfate inhibitors. There are three methods carried out, starting from the thermal stability test, static bottle test, and dynamic scale loop test. The inhibition performance tests were done at temperatures of 50°C, 70°C, and 90°C. The inhibitor concentration was varied from 10, 50, 100, 1000 until 10000 ppm. The results indicate that both HEC and CMC have the potency to be used as inhibitors for these two types of scales. Both results from the static bottle test and dynamic scale loop test indicate that HEC and CMC were able to inhibit the formation of the tested scale, yet they have not been able to completely inhibit 100% of scale formation.
{"title":"Laboratory Study on the Use of Novel Biodegradable Scale Inhibitors Against Mixed Calcium Carbonate and Calcium Sulfate Scale","authors":"U. Z. Husna, K. Elraies, J. A. Shuhili, R. Tewari","doi":"10.4043/31492-ms","DOIUrl":"https://doi.org/10.4043/31492-ms","url":null,"abstract":"\u0000 The development of the scale layers in oil and gas operation results in production losses and equipment instability because of pipeline blockage, energy leak, corrosion acceleration and severe accidents which will impact the safety of production. Among many types of scales, calcium carbonate and calcium sulfate are considered the most frequent, prominent and terrible. On the other hand, cellulose is a class of natural polymers and also contains abundant functional groups including hydroxyl, carboxyl, and amino groups, resulting in good chelation and dispersion effects. They possess good physical and chemical properties, thermal stability, and biodegradability, abundantly available and inexpensive which make them promising compounds for the creation of \"green\" oil field reagents, including scale inhibitor. In this study, we tested two types of biodegradable polymers named hydroxyethyl cellulose (HEC) and carboxymethyl cellulose (CMC) for application as calcium carbonate and mixed carbonate and sulfate inhibitors. There are three methods carried out, starting from the thermal stability test, static bottle test, and dynamic scale loop test. The inhibition performance tests were done at temperatures of 50°C, 70°C, and 90°C. The inhibitor concentration was varied from 10, 50, 100, 1000 until 10000 ppm. The results indicate that both HEC and CMC have the potency to be used as inhibitors for these two types of scales. Both results from the static bottle test and dynamic scale loop test indicate that HEC and CMC were able to inhibit the formation of the tested scale, yet they have not been able to completely inhibit 100% of scale formation.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"69 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85201147","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 year 2020 has been challenging for the whole world due to the COVID pandemic. The unprecedented impacts of the world's recent lockdown and volatility of oil and gas markets tested the leadership and resilience of business models and repositioned strategies that will shape the industry for the next decade. Business survival has become critical during these unprecedented times, especially in the energy industry which has taken a significant hit due to the oil price fall and supply gluts. Existing plans are under observation, as it is vital to identify more efficient approaches and solutions for building future business resilience. Modern technologies can be used to support energy transition. The surface jet pump is one of the newest technologies that help lower the wellhead pressure of the well. It also reduces back pressure on the well. Thus, it enhances the flow rate. Additionally, the surface jet pump overcomes the flow line pressure into the existing pressurized flow lines without creating back pressure on the reservoirs. This technology can be utilized for many applications, including well-bore cleanup after completions, de-liquefying gas wells, producing heavy, viscous, or corrosive liquids, producing CO2 and natural gas wells. This paper is about the successful installation of the first-ever surface jet pump in the country. The pump was deployed in the Northern Iraq region to reduce the backpressure on the wells caused by the central production facility. The pump parameters were designed on Jet Evaluation and Modeling Software (JEMS) and 13G was selected as the optimum nozzle and throat combination for this project. The pump worked successfully, and the wellhead increased from 310 to 355 psi. And gross production from a single well was increased to around 850 BPD from 550 BPD generating about 0.4 Million USD/Month additional revenue. With the long-term impact of the recent pandemic on the energy market, it's clear that companies are more focused than ever on picking the best solutions to ensure the long-term viability and survival of their operations. The surface jet pump is one of the technological advancements for such solutions that have been successfully tested at this location. This paper goes on the technicalities of the technology and project.
受新冠肺炎疫情影响，2020年对全世界来说都是充满挑战的一年。最近全球石油和天然气市场的封锁和波动带来了前所未有的影响，考验了商业模式的领导力和弹性，并重新定位了将在未来十年塑造该行业的战略。在这个前所未有的时代，企业的生存变得至关重要，尤其是在能源行业，由于油价下跌和供应过剩，能源行业受到了重大打击。我们正在观察现有计划，因为确定构建未来业务弹性的更有效的方法和解决方案至关重要。现代技术可用于支持能源转型。地面喷射泵是帮助降低井口压力的最新技术之一。它还减少了井的背压。因此，它提高了流量。此外，地面喷射泵克服了流线压力进入现有的加压流线，而不会对储层产生背压。该技术可用于许多应用，包括完井后的井筒清理、气井的液化、生产重质、粘性或腐蚀性液体、生产二氧化碳和天然气井。本文是关于国内第一个地面喷射泵的成功安装。该泵被部署在伊拉克北部地区，以减少中央生产设施对油井造成的背压。在射流评价与建模软件(Jet Evaluation and Modeling Software, JEMS)上设计了泵的参数，并选择13G作为本项目的最佳喷嘴和喉道组合。该泵工作成功，井口压力从310 psi增加到355 psi。单口井的总产量从550桶/天增加到850桶/天左右，每月产生约40万美元的额外收入。鉴于近期疫情对能源市场的长期影响，很明显，企业比以往任何时候都更加注重选择最佳解决方案，以确保其业务的长期可行性和生存能力。地面喷射泵是此类解决方案的技术进步之一，已在该地点成功进行了测试。本文对该技术和项目的技术性进行了论述。
{"title":"Overcoming High Flow Line Pressure by Successful Installation of First Surface Jet Pump","authors":"Abid Ur Rehman, M. Abdelbary, Kamaran Azeez","doi":"10.4043/31613-ms","DOIUrl":"https://doi.org/10.4043/31613-ms","url":null,"abstract":"\u0000 The year 2020 has been challenging for the whole world due to the COVID pandemic. The unprecedented impacts of the world's recent lockdown and volatility of oil and gas markets tested the leadership and resilience of business models and repositioned strategies that will shape the industry for the next decade. Business survival has become critical during these unprecedented times, especially in the energy industry which has taken a significant hit due to the oil price fall and supply gluts.\u0000 Existing plans are under observation, as it is vital to identify more efficient approaches and solutions for building future business resilience. Modern technologies can be used to support energy transition. The surface jet pump is one of the newest technologies that help lower the wellhead pressure of the well. It also reduces back pressure on the well. Thus, it enhances the flow rate. Additionally, the surface jet pump overcomes the flow line pressure into the existing pressurized flow lines without creating back pressure on the reservoirs. This technology can be utilized for many applications, including well-bore cleanup after completions, de-liquefying gas wells, producing heavy, viscous, or corrosive liquids, producing CO2 and natural gas wells.\u0000 This paper is about the successful installation of the first-ever surface jet pump in the country. The pump was deployed in the Northern Iraq region to reduce the backpressure on the wells caused by the central production facility. The pump parameters were designed on Jet Evaluation and Modeling Software (JEMS) and 13G was selected as the optimum nozzle and throat combination for this project. The pump worked successfully, and the wellhead increased from 310 to 355 psi. And gross production from a single well was increased to around 850 BPD from 550 BPD generating about 0.4 Million USD/Month additional revenue.\u0000 With the long-term impact of the recent pandemic on the energy market, it's clear that companies are more focused than ever on picking the best solutions to ensure the long-term viability and survival of their operations. The surface jet pump is one of the technological advancements for such solutions that have been successfully tested at this location. This paper goes on the technicalities of the technology and project.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85264655","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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