Easy oil is no longer low hanging fruit for oil and gas operators, and drilling targets are becoming increasingly ambitious, which results in escalation of the well trajectory complexity. This accordingly spirals the well and completion costs. To overcome this situation, technology must play a role to reduce cost, increase efficiency and ensure safety at all times. Conveyance is the key for any data acquisition and well completion activities. Historically, conveyance methods for data acquisition and perforation in highly deviated or horizontal wells required drill pipe or coiled-tubing methods. These methods are time consuming, labor intensive, require a larger equipment footprint, with possible HSE risks involved. Mubadala Petroleum in Thailand has seen a significant increase in horizontal and high deviated wells over the past few years. The wireline tractor technology has been used for the first time in Mubadala Petroleum's Thailand operations during the drilling, initial completion and workover intervention operations, and it has been a game changer for Mubadala Petroleum in Thailand in terms of reducing rig time, well cost, and most importantly minimizing the HSE risks. Over the past few decades, the oil and gas industry has developed the technique of drilling horizontally through the reservoir to maximize the surface contact area of the reservoir, to gain higher recovery and production. However, one downside from this technique is that it has become challenging and costly to perforate or to obtain measurements in this horizontal environment, as gravity will no longer support the wireline tools to reach to the bottom of the well. Wireline Tractor technology has played an important role to overcome this challenge. It reduces time, cost and will improve data quality as well as increase wellbore coverage. The wireline tractor functions with an electric over hydraulic power relationship, using its drive/wheel sections to push the passenger tool downhole as the cable is spooled off the unit allowing the tool to reach the end of horizontal or deviated wells without deploying drill pipe or coiled tubing conveyance methods. With this principle, any job that is typically run on electric wireline in a vertical well can be efficiently done in a horizontal or deviated well using wireline tractor. Material presented in the paper will be from actual operations, examples being tractor conveyed wireline logging tool and 4.5in Outer Diameter (OD) 90 ft heavy long perforation gun in single tractor operations. It will also display the operational efficiencies increases and risk reduction being obtained.
{"title":"Wireline Tractor Conveyance - A Technology Game Changer for the Gulf of Thailand","authors":"Sarunya Jongnarungsin, Toon Puttisounthorn","doi":"10.2118/192672-MS","DOIUrl":"https://doi.org/10.2118/192672-MS","url":null,"abstract":"\u0000 Easy oil is no longer low hanging fruit for oil and gas operators, and drilling targets are becoming increasingly ambitious, which results in escalation of the well trajectory complexity. This accordingly spirals the well and completion costs. To overcome this situation, technology must play a role to reduce cost, increase efficiency and ensure safety at all times. Conveyance is the key for any data acquisition and well completion activities. Historically, conveyance methods for data acquisition and perforation in highly deviated or horizontal wells required drill pipe or coiled-tubing methods. These methods are time consuming, labor intensive, require a larger equipment footprint, with possible HSE risks involved. Mubadala Petroleum in Thailand has seen a significant increase in horizontal and high deviated wells over the past few years. The wireline tractor technology has been used for the first time in Mubadala Petroleum's Thailand operations during the drilling, initial completion and workover intervention operations, and it has been a game changer for Mubadala Petroleum in Thailand in terms of reducing rig time, well cost, and most importantly minimizing the HSE risks.\u0000 Over the past few decades, the oil and gas industry has developed the technique of drilling horizontally through the reservoir to maximize the surface contact area of the reservoir, to gain higher recovery and production. However, one downside from this technique is that it has become challenging and costly to perforate or to obtain measurements in this horizontal environment, as gravity will no longer support the wireline tools to reach to the bottom of the well. Wireline Tractor technology has played an important role to overcome this challenge. It reduces time, cost and will improve data quality as well as increase wellbore coverage. The wireline tractor functions with an electric over hydraulic power relationship, using its drive/wheel sections to push the passenger tool downhole as the cable is spooled off the unit allowing the tool to reach the end of horizontal or deviated wells without deploying drill pipe or coiled tubing conveyance methods. With this principle, any job that is typically run on electric wireline in a vertical well can be efficiently done in a horizontal or deviated well using wireline tractor.\u0000 Material presented in the paper will be from actual operations, examples being tractor conveyed wireline logging tool and 4.5in Outer Diameter (OD) 90 ft heavy long perforation gun in single tractor operations. It will also display the operational efficiencies increases and risk reduction being obtained.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85357894","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 Ceduna Sub-basin is one of the few remaining frontier basins in Australia today. Few exploration wells have been drilled in the basin and none have encountered hydrocarbons. The current study aims to investigate the hydrocarbon prospectivity of an area of interest (AOI) within the distal part of the Ceduna Sub-basin, where no well information is available. The study uses 3D seismic data and employs principles from geophysics, structural geology, sedimentology, sequence stratigraphy, and petroleum systems analysis in a comprehensive investigation to understand the Ceduna Sub-basin. Multiple 2D basin models were created for the AOI to test different scenarios in a detailed risk analysis of the petroleum system and its major controls. They were identified from a comprehensive literature review and after a thorough interpretation of the 3D seismic survey in the AOI. Results show that the best reservoir is located within the low stand systems tract (LST) deposits of the Hammerhead Sandstone (Ss) and Top Tiger Ss. The potential source rock occurs in the condensed high stand system tract (HST) deposits in the Base Tiger Ss and White Pointer Ss. 1D modeling showed that these source rocks may have generated hydrocarbons as their depth is <9 km. The critical moment during the source rock history was at 80 Ma coinciding with the deposition of the Hammerhead Ss. Based on the regional structural framework, faults were initiated after source rock deposition. Several growth faults may pose a risk in terms of hydrocarbon leakage. Different 2D models have advanced the understanding of the petroleum systems in the AOI. The results showed that the most prospective areas are within a rollover anticline play and those areas where intra-formational seals are present. The model confirms that fault integrity represents the prime risk across the basin. The current study contributes to understanding of the Ceduna Sub-basin by identifying two different plays in the AOI: rollover anticline and tilted fault block. Probability analysis of the different petroleum elements shows that the rollover anticline play has the highest geological probability of success.
{"title":"A Petroleum Systems Analysis and Characterization of the Frontier Ceduna Sub-Basin in Australia","authors":"A. Alghuraybi, A. Harthi, Ahlam Al Jabry","doi":"10.2118/192908-MS","DOIUrl":"https://doi.org/10.2118/192908-MS","url":null,"abstract":"\u0000 \u0000 \u0000 The Ceduna Sub-basin is one of the few remaining frontier basins in Australia today. Few exploration wells have been drilled in the basin and none have encountered hydrocarbons. The current study aims to investigate the hydrocarbon prospectivity of an area of interest (AOI) within the distal part of the Ceduna Sub-basin, where no well information is available.\u0000 \u0000 \u0000 \u0000 The study uses 3D seismic data and employs principles from geophysics, structural geology, sedimentology, sequence stratigraphy, and petroleum systems analysis in a comprehensive investigation to understand the Ceduna Sub-basin. Multiple 2D basin models were created for the AOI to test different scenarios in a detailed risk analysis of the petroleum system and its major controls. They were identified from a comprehensive literature review and after a thorough interpretation of the 3D seismic survey in the AOI.\u0000 \u0000 \u0000 \u0000 Results show that the best reservoir is located within the low stand systems tract (LST) deposits of the Hammerhead Sandstone (Ss) and Top Tiger Ss. The potential source rock occurs in the condensed high stand system tract (HST) deposits in the Base Tiger Ss and White Pointer Ss. 1D modeling showed that these source rocks may have generated hydrocarbons as their depth is <9 km. The critical moment during the source rock history was at 80 Ma coinciding with the deposition of the Hammerhead Ss.\u0000 Based on the regional structural framework, faults were initiated after source rock deposition. Several growth faults may pose a risk in terms of hydrocarbon leakage. Different 2D models have advanced the understanding of the petroleum systems in the AOI. The results showed that the most prospective areas are within a rollover anticline play and those areas where intra-formational seals are present. The model confirms that fault integrity represents the prime risk across the basin.\u0000 \u0000 \u0000 \u0000 The current study contributes to understanding of the Ceduna Sub-basin by identifying two different plays in the AOI: rollover anticline and tilted fault block. Probability analysis of the different petroleum elements shows that the rollover anticline play has the highest geological probability of success.\u0000","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"83 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81093199","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. Khalil, R. Agrawal, F. Kamal, Oussama Takieddine
Members forming part of structures exposed to cyclic loading (such as offshore oil and gas platforms) are engineered to satisfy various pre-service and in-service loading conditions which include being checked for compliance with fatigue design requirements. In this study, the parameters that affect welded tubular joint fatigue performance are identified to assist design engineers achieve a preliminary design that is more likely to satisfy the fatigue design requirements early in the design cycle with the aim of avoiding later changes in the design. State-of-the-art Finite Element modelling techniques were implemented throughout the course of this study. For a selected typical K-T joint from a 3D support frame ‘Study Model’ initially created in SACS (Structural Analysis Computer Software) was replicated in ANSYS and variations in Stress Concentation Factor (SCF), Hot Spot Stress (HSS) and fatigue life were studied with respect to variable joint properties, namely brace to chord diameter ratio (d/D), brace to chord thickness ratio (t/T) and brace diameter to thickness ratio (d/t). Results obtained from both programs were compared as means for validation of study model. Following the validation process, the same principles were applied to the Case Study. The Study Model - found a good correlation between the trend of variation of results obtained from Nominal Stress Approach and Hot Spot Stress Approach. This serves the purpose of validating the Nominal Stress Approach methodology which shall then be used in the Case Study. Case Study- Fixed Offshore Platform- Fatigue Life predicted longer for joints with d/D in the range 0.41 to 0.44 for constant member combined stress utilization ratio (UCR) and constant t/T. Fatigue Life predicted longer for joints with t/T in the range 0.345 to 0.375 for constant member UCR and constant d/D. Fatigue Life predicted longer for joints with d/t in the range 28 to 36 for constant member UCR, constant d/D and constant t/T. Engineering Consultants and EPC Contractors executing projects involving detailed engineering through to installation of fixed offshore platforms perform structural analysis to define material requirements. Performing fatigue analyses for the final outcome of static in-service analysis may result in re-sizing of members during the course of the design cycle. The joint parameters derived by this paper can be applied at an early stage of the design process with the aim of confidently defining sizing of tubular joints that are likely to satisfy fatigue design requirements. This greatly enhances engineering efficiency by avoiding later design changes in the design cycle.
{"title":"Case Study for Early Design Optimization of Fatigue Sensitive Tubular Connections in Fixed Offshore Platforms","authors":"A. Khalil, R. Agrawal, F. Kamal, Oussama Takieddine","doi":"10.2118/192864-MS","DOIUrl":"https://doi.org/10.2118/192864-MS","url":null,"abstract":"\u0000 Members forming part of structures exposed to cyclic loading (such as offshore oil and gas platforms) are engineered to satisfy various pre-service and in-service loading conditions which include being checked for compliance with fatigue design requirements. In this study, the parameters that affect welded tubular joint fatigue performance are identified to assist design engineers achieve a preliminary design that is more likely to satisfy the fatigue design requirements early in the design cycle with the aim of avoiding later changes in the design.\u0000 State-of-the-art Finite Element modelling techniques were implemented throughout the course of this study. For a selected typical K-T joint from a 3D support frame ‘Study Model’ initially created in SACS (Structural Analysis Computer Software) was replicated in ANSYS and variations in Stress Concentation Factor (SCF), Hot Spot Stress (HSS) and fatigue life were studied with respect to variable joint properties, namely brace to chord diameter ratio (d/D), brace to chord thickness ratio (t/T) and brace diameter to thickness ratio (d/t). Results obtained from both programs were compared as means for validation of study model. Following the validation process, the same principles were applied to the Case Study.\u0000 The Study Model - found a good correlation between the trend of variation of results obtained from Nominal Stress Approach and Hot Spot Stress Approach. This serves the purpose of validating the Nominal Stress Approach methodology which shall then be used in the Case Study.\u0000 Case Study- Fixed Offshore Platform- Fatigue Life predicted longer for joints with d/D in the range 0.41 to 0.44 for constant member combined stress utilization ratio (UCR) and constant t/T. Fatigue Life predicted longer for joints with t/T in the range 0.345 to 0.375 for constant member UCR and constant d/D. Fatigue Life predicted longer for joints with d/t in the range 28 to 36 for constant member UCR, constant d/D and constant t/T.\u0000 Engineering Consultants and EPC Contractors executing projects involving detailed engineering through to installation of fixed offshore platforms perform structural analysis to define material requirements. Performing fatigue analyses for the final outcome of static in-service analysis may result in re-sizing of members during the course of the design cycle. The joint parameters derived by this paper can be applied at an early stage of the design process with the aim of confidently defining sizing of tubular joints that are likely to satisfy fatigue design requirements. This greatly enhances engineering efficiency by avoiding later design changes in the design cycle.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84347946","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 described the novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution within a High Resolution Sequence Stratigraphy (HRSS) framework. The carbonate lithofacies discussed in this paper contains heterogeneous pore types and properties. The reservoir displays an extensive range of geologic and petrophysical properties that make the efficient recovery of hydrocarbons is a challenging task. Hence one of the key steps in improving the recovery factor is by defining the three dimensional variability patterns in the reservoir in the form of fine geocellular static model. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties. Subsurface analysis was done by examining 600 feet core footage from more than 15 wells, conventional logs from more than 50 wells, and more than 350 thin sections. The reservoir section averages 35 feet that can be subdivided into 6 high-frequency sequences. The reservoir consists of lagoonal packstone-rudstone, grain rich ooid-peloid shoal, and rudstone-boundstone mid-ramp. The shoal deposits exhibit the best permeability and oil saturation and it consists of discontinuous lithofacies body that depicts locally excellent porosity and permeability characteristics. Lithofacies geometry and properties studies must form a fundamental basis for characterizing and modeling HRSS framework and lithofacies architecture variability through the reservoir. Combined with wireline-log data, they provide a basis for defining both reservoir framework and rock attribute distributions. Complex lithofacies geometries and transitions, both vertically and laterally between the mound and discontinuous grain-rich ooid-peloid shoal lithofacies together with the continuous and sequential lagoonal and mid-ramp lithofacies does not allow to simulate these sorts of lithofacies assemblage using single lithofacies model algorithm. Hence a new holistic approach was implemented. A combination of Object Based (OB) algorithm and Truncated Gaussian Simulation (TGS) algorithm was employed to handle the complex lithofacies transition. This enables generating multiple realistic field wide lithofacies distribution and relationship which aligns with data trend, subsurface analog in the nearby fields, as well as that is from the outcrop exposure. The established lithofacies distribution within HRSS framework was then used to constrain field-wide properties and diagenetic trend and distribution in the reservoir. This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target
{"title":"Sequence Stratigraphy and Geostatistical Realizations Integration: A Holistic Approach in Constructing a Complex Carbonate Reservoir Model","authors":"A. Salahuddin, K. Khan, R. A. Ali, K. Hammadi","doi":"10.2118/192896-MS","DOIUrl":"https://doi.org/10.2118/192896-MS","url":null,"abstract":"\u0000 This paper described the novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution within a High Resolution Sequence Stratigraphy (HRSS) framework. The carbonate lithofacies discussed in this paper contains heterogeneous pore types and properties. The reservoir displays an extensive range of geologic and petrophysical properties that make the efficient recovery of hydrocarbons is a challenging task. Hence one of the key steps in improving the recovery factor is by defining the three dimensional variability patterns in the reservoir in the form of fine geocellular static model. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties.\u0000 Subsurface analysis was done by examining 600 feet core footage from more than 15 wells, conventional logs from more than 50 wells, and more than 350 thin sections. The reservoir section averages 35 feet that can be subdivided into 6 high-frequency sequences. The reservoir consists of lagoonal packstone-rudstone, grain rich ooid-peloid shoal, and rudstone-boundstone mid-ramp. The shoal deposits exhibit the best permeability and oil saturation and it consists of discontinuous lithofacies body that depicts locally excellent porosity and permeability characteristics.\u0000 Lithofacies geometry and properties studies must form a fundamental basis for characterizing and modeling HRSS framework and lithofacies architecture variability through the reservoir. Combined with wireline-log data, they provide a basis for defining both reservoir framework and rock attribute distributions.\u0000 Complex lithofacies geometries and transitions, both vertically and laterally between the mound and discontinuous grain-rich ooid-peloid shoal lithofacies together with the continuous and sequential lagoonal and mid-ramp lithofacies does not allow to simulate these sorts of lithofacies assemblage using single lithofacies model algorithm. Hence a new holistic approach was implemented. A combination of Object Based (OB) algorithm and Truncated Gaussian Simulation (TGS) algorithm was employed to handle the complex lithofacies transition. This enables generating multiple realistic field wide lithofacies distribution and relationship which aligns with data trend, subsurface analog in the nearby fields, as well as that is from the outcrop exposure. The established lithofacies distribution within HRSS framework was then used to constrain field-wide properties and diagenetic trend and distribution in the reservoir.\u0000 This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86574837","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}
Advanced Non Destructive Testing (NDT) techniques rely on consistent acquisition of data and its reliable analysis. As technology advances, new challenges emerge. For instance, the amount of data produced is exceeding the qualified personnel available for data analysis; moreover, the files produced can be easily handle unethically. Our project proposes the implementation of Artificial Intelligence (AI) techniques to develop algorithms to better harness the data available, in order to enhance the quality of data analysis and better monitor ethical practices. Method: For any NDT technique, the consistency of the results and the reliability of the findings depends heavily on the personnel performing the inspections and evaluating the results. As more advanced NDT techniques are available in the areas of ultrasound, digital data becomes available opening the door for intelligent tools for analysing and handling ultrasound data. This project proposes an innovative analysis software based on Computational Intelligence (CI) techniques. The implementation of this software reduces the time needed for a single analysis and the consistency of results, more importantly; it can be use as an audit tool to ensure data files have not been mishandle. For the first stage of the proposed CI cloud-based software, the data collected by the inspector is send via internet connection to web-based servers. During the second stage, the data will be verify for quality; if any data is missing or poor-quality is detected, the software will inform the inspector that data must be resubmitted. Once the verification of data is completed, the data analysis is then perform by CI-based algorithms, which can recognise and classify features within the data such as geometry indications, anomalies and defects. Following the CI-based analysis, the software generates a complete report and the results are be available to the user via a 3D visualization interface. This report includes details of sizing, characterisation, location of defects, geometry indications and other relevant information related to the analysed data. The information contained in the interface and generated by the software will be available to the final user for validation and approval. The CI-based analysis tools have already been use to monitor several data files from NDT inspections using Phased Array Ultrasound (PAUT) and the results have successfully verify the authenticity of the ultrasound raw data, which is a critical verification step and evidence of any mal practices or mistakes of data handling. There is a lack of reliable tools available to NDT experts that can facilitate the task of analysing data; this innovative software takes advantage of the CI techniques and expert knowledge to address this issue. Furthermore, our approach offers a high degree of consistency for identifying defects; improves the quality of the analysis and reduces the time invested in such critical NDT duty. Aud
{"title":"Artificial Intelligence Aproaches as Tools for Auditing and Improving Data Analysis of Advanced Ultrasound Techniques in Non-Destructive Testing","authors":"Neil Harrap, R. Rhéaume, A. Gosselin","doi":"10.2118/193088-MS","DOIUrl":"https://doi.org/10.2118/193088-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Advanced Non Destructive Testing (NDT) techniques rely on consistent acquisition of data and its reliable analysis. As technology advances, new challenges emerge. For instance, the amount of data produced is exceeding the qualified personnel available for data analysis; moreover, the files produced can be easily handle unethically. Our project proposes the implementation of Artificial Intelligence (AI) techniques to develop algorithms to better harness the data available, in order to enhance the quality of data analysis and better monitor ethical practices.\u0000 Method: For any NDT technique, the consistency of the results and the reliability of the findings depends heavily on the personnel performing the inspections and evaluating the results. As more advanced NDT techniques are available in the areas of ultrasound, digital data becomes available opening the door for intelligent tools for analysing and handling ultrasound data. This project proposes an innovative analysis software based on Computational Intelligence (CI) techniques. The implementation of this software reduces the time needed for a single analysis and the consistency of results, more importantly; it can be use as an audit tool to ensure data files have not been mishandle.\u0000 \u0000 \u0000 \u0000 For the first stage of the proposed CI cloud-based software, the data collected by the inspector is send via internet connection to web-based servers. During the second stage, the data will be verify for quality; if any data is missing or poor-quality is detected, the software will inform the inspector that data must be resubmitted.\u0000 Once the verification of data is completed, the data analysis is then perform by CI-based algorithms, which can recognise and classify features within the data such as geometry indications, anomalies and defects. Following the CI-based analysis, the software generates a complete report and the results are be available to the user via a 3D visualization interface. This report includes details of sizing, characterisation, location of defects, geometry indications and other relevant information related to the analysed data. The information contained in the interface and generated by the software will be available to the final user for validation and approval.\u0000 The CI-based analysis tools have already been use to monitor several data files from NDT inspections using Phased Array Ultrasound (PAUT) and the results have successfully verify the authenticity of the ultrasound raw data, which is a critical verification step and evidence of any mal practices or mistakes of data handling.\u0000 \u0000 \u0000 \u0000 There is a lack of reliable tools available to NDT experts that can facilitate the task of analysing data; this innovative software takes advantage of the CI techniques and expert knowledge to address this issue. Furthermore, our approach offers a high degree of consistency for identifying defects; improves the quality of the analysis and reduces the time invested in such critical NDT duty. Aud","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91239557","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. Yugay, A. Gadelhak, G. Pimenta, Mariam Mansoor Al Reyami
In early 80's in ADNOC Onshore standard well completion design for gas producers in Reservoir Y of Bab field was a combination of L-80 carbon steel with a downhole continuous corrosion inhibitor injection above the Chemical Injection Valve (CIV) and Corrosion Resistant Alloy (CRA) Incoloy 825 / SM25Cr-75 below the CIV and packer. In 1994 (after 10 years of operation), due to the fact that no integrity issues were observed, it was decided to maintain the same design strategy was followed in all new gas producer wells in this reservoir. Identical design strategy was followed for Reservoir X (Project-I) gas wells which presented less severe fluid conditions. Table 1 summarizes reservoir conditions for both reservoir X and Y.
{"title":"Well Design Evolution, Validation and Optimization in ADNOC Onshore GAS Field","authors":"A. Yugay, A. Gadelhak, G. Pimenta, Mariam Mansoor Al Reyami","doi":"10.2118/192836-MS","DOIUrl":"https://doi.org/10.2118/192836-MS","url":null,"abstract":"\u0000 In early 80's in ADNOC Onshore standard well completion design for gas producers in Reservoir Y of Bab field was a combination of L-80 carbon steel with a downhole continuous corrosion inhibitor injection above the Chemical Injection Valve (CIV) and Corrosion Resistant Alloy (CRA) Incoloy 825 / SM25Cr-75 below the CIV and packer.\u0000 In 1994 (after 10 years of operation), due to the fact that no integrity issues were observed, it was decided to maintain the same design strategy was followed in all new gas producer wells in this reservoir. Identical design strategy was followed for Reservoir X (Project-I) gas wells which presented less severe fluid conditions. Table 1 summarizes reservoir conditions for both reservoir X and Y.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"35 42","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91549776","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 use of electrical submersible pumps (ESPs) is a highly effective artificial lift method for boosting oil production from wells operating in both onshore and offshore fields. When an ESP is deployed, its complete pump and electrical motor assembly is positioned below the surface within the oil reservoir that the well has tapped. Once deployed, the ESPs must be carefully maintained to be highly reliable and always available to prevent costly production disruptions due to unexpected pump failures. Typically, ESPs are connected to SCADA or other distributed control systems to provide supervisory and control functions for their effective operation as well as for operational visibility. Today, many diagnostic methods are available to determine the health and status of an ESP system by making use of that functionality in its automation system. However, while these methods can provide insightful analysis of problems, they usually only provide retrospective views after failure events have occurred. But this situation is changing. With recent advances in artificial intelligence (AI) combined with the new Internet of Things (IoT) technologies, it is possible to effectively use data-driven analytics fueled by large data sets. In particular, AI technology that involves deep learning and neural networks can be extremely effective in detecting abnormal behavior of complex physical systems such as ESPs, based on the data gathered from the system, providing decision support for remediating or managing the causative issues. This paper focuses on the results of implementing this AI technology combination to detect, flag, and remediate abnormal behavior for ESPs, which can increase their availability and prevent production disruptions. The subject use case involved 30 ESPs, with pumps ranging from 200–500 kW in power, installed in a medium-depth onshore oil field. The paper discusses the architecture of the solution that was deployed and explain how it supports a predictive maintenance model that is capable of accurately identifying abnormal ESP operating behaviors in advance before an ESP can fail and disrupt production.
{"title":"Usage of Artificial Intelligence to Reduce Operational Disruptions of ESPs by Implementing Predictive Maintenance","authors":"Nico Jansen van Rensburg","doi":"10.2118/192610-ms","DOIUrl":"https://doi.org/10.2118/192610-ms","url":null,"abstract":"\u0000 The use of electrical submersible pumps (ESPs) is a highly effective artificial lift method for boosting oil production from wells operating in both onshore and offshore fields. When an ESP is deployed, its complete pump and electrical motor assembly is positioned below the surface within the oil reservoir that the well has tapped. Once deployed, the ESPs must be carefully maintained to be highly reliable and always available to prevent costly production disruptions due to unexpected pump failures.\u0000 Typically, ESPs are connected to SCADA or other distributed control systems to provide supervisory and control functions for their effective operation as well as for operational visibility. Today, many diagnostic methods are available to determine the health and status of an ESP system by making use of that functionality in its automation system. However, while these methods can provide insightful analysis of problems, they usually only provide retrospective views after failure events have occurred.\u0000 But this situation is changing. With recent advances in artificial intelligence (AI) combined with the new Internet of Things (IoT) technologies, it is possible to effectively use data-driven analytics fueled by large data sets. In particular, AI technology that involves deep learning and neural networks can be extremely effective in detecting abnormal behavior of complex physical systems such as ESPs, based on the data gathered from the system, providing decision support for remediating or managing the causative issues.\u0000 This paper focuses on the results of implementing this AI technology combination to detect, flag, and remediate abnormal behavior for ESPs, which can increase their availability and prevent production disruptions. The subject use case involved 30 ESPs, with pumps ranging from 200–500 kW in power, installed in a medium-depth onshore oil field. The paper discusses the architecture of the solution that was deployed and explain how it supports a predictive maintenance model that is capable of accurately identifying abnormal ESP operating behaviors in advance before an ESP can fail and disrupt production.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86313521","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}
Supplier Performance Management (SPM) is a process to improve the overall performance of Suppliers, promote better working relationships with Suppliers and remove poor performing suppliers from Pre-qualified Bidders List. Once SPM is in place Supplier Performance can be tracked, analyzed and shared with confidence. Owner company can clearly identify poor performing Suppliers and work with them to improve their performance. The steps involved in achieving an effective SPM are Measure Supplier performance, Analyze available data, Communicate/Engage Supplier and work for tangible Improvement.
{"title":"Manage Performance of Suppliers Effectively to Achieve Excellence in Supply Chain","authors":"M. Kashif","doi":"10.2118/192613-MS","DOIUrl":"https://doi.org/10.2118/192613-MS","url":null,"abstract":"\u0000 Supplier Performance Management (SPM) is a process to improve the overall performance of Suppliers, promote better working relationships with Suppliers and remove poor performing suppliers from Pre-qualified Bidders List.\u0000 Once SPM is in place Supplier Performance can be tracked, analyzed and shared with confidence. Owner company can clearly identify poor performing Suppliers and work with them to improve their performance.\u0000 The steps involved in achieving an effective SPM are Measure Supplier performance, Analyze available data, Communicate/Engage Supplier and work for tangible Improvement.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"130 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86319702","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 objective of the Study was to recommend the most techno-economic option to maximize the NGL Recovery at existing Gas Processing Complex by assessing all the facilities in the complete processing chain from Offshore to Onshore and evaluating the potential options and their associated bottlenecks, production impact and business interruption in order to address the changes in gas supply to the existing Gas Processing Complex from various sources and developments. The Study was conducted in 3 stages: Feasibility Study was carried out and recommended to install two NGL Recovery Trains with huge capital investment.Gap Analysis and Idea Innovation - The alternative idea of maximizing utilization of existing facilities and energy with minimum modifications was developed by re-distributing the feed streams based on their richness in NGL content within existing facilities so that the optimum NGL Recovery can be achieved.Pre-Feed Study – The developed idea along with other potential options were thoroughly evaluated by a Pre-FEED Study to select the most techno-economic feasible option. The concept of maximizing utilization of existing facilities and re-distribution of gas according to their qualities offers outstanding benefits to its shareholders: Considerable saving in capital investment ~ 98.64% and energy saving of ~ 18 MWminimum modifications at Offshore Facilities and Existing Gas Processing Complex which could be carried-out during a planned Shut Down and without impacting the production targets.High Net Present ValueReversible design and operationNo long lead items This paper represents the change in typical approach of installation of new facilities to accommodate the increase in gas supply to a holistic approach of efficient utilization of existing facilities and energy to generate more values to business by generating more revenues with minimum modifications and offering facilities which will be fit for purpose and potential future developments.
{"title":"Efficient Utilization of Existing Facilities and Energy in Gas Processing","authors":"A. Vyas","doi":"10.2118/193263-MS","DOIUrl":"https://doi.org/10.2118/193263-MS","url":null,"abstract":"\u0000 The objective of the Study was to recommend the most techno-economic option to maximize the NGL Recovery at existing Gas Processing Complex by assessing all the facilities in the complete processing chain from Offshore to Onshore and evaluating the potential options and their associated bottlenecks, production impact and business interruption in order to address the changes in gas supply to the existing Gas Processing Complex from various sources and developments.\u0000 The Study was conducted in 3 stages: Feasibility Study was carried out and recommended to install two NGL Recovery Trains with huge capital investment.Gap Analysis and Idea Innovation - The alternative idea of maximizing utilization of existing facilities and energy with minimum modifications was developed by re-distributing the feed streams based on their richness in NGL content within existing facilities so that the optimum NGL Recovery can be achieved.Pre-Feed Study – The developed idea along with other potential options were thoroughly evaluated by a Pre-FEED Study to select the most techno-economic feasible option.\u0000 The concept of maximizing utilization of existing facilities and re-distribution of gas according to their qualities offers outstanding benefits to its shareholders: Considerable saving in capital investment ~ 98.64% and energy saving of ~ 18 MWminimum modifications at Offshore Facilities and Existing Gas Processing Complex which could be carried-out during a planned Shut Down and without impacting the production targets.High Net Present ValueReversible design and operationNo long lead items\u0000 This paper represents the change in typical approach of installation of new facilities to accommodate the increase in gas supply to a holistic approach of efficient utilization of existing facilities and energy to generate more values to business by generating more revenues with minimum modifications and offering facilities which will be fit for purpose and potential future developments.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87391094","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 today's oil prices scenario, industry's focus is shifting towards Brownfield projects having low CAPEX utilizing existing Oil & Gas assets. Towards this objective, de-bottlenecking of existing flare system becomes inevitable for facilities up-gradation. The spare capacity of existing flare is utilized to accommodate additional relief loads from new facility, thus avoiding installation of new flare. Dynamic simulation approach provides significant advantages over conventional approach in terms of realistic estimation of flare capacity and optimal use of existing plant assets. The conventional steady state approach assumptions provide conservative relief loads considering sum of instantaneous peak flows of relieving devices irrespective of their opening time. Flare operations are inherently dynamic in nature and dynamic simulations provide more realistic relief loads and presents optimal approach to de-bottlenecking of existing flare system. Latest API approach to determine relief rate based on Fire Response Analysis using vessel rupture acceptance criteria also provides additional benefits in terms of relief load optimization as compared to conventional API approach to reduce the system pressure to 50% or 100 Psig in 15 minutes. Dynamic approach also accounts for the packing effect in flare network, system operating pressure at which blow down will initiate and sequential opening of blow down valves for each isolatable section. Thus, dynamic approach provides better understanding of the dynamic behavior during blow down scenario. The flare system of offshore gas processing platform was originally designed based on steady state approach, commonly used being a conservative design which is more appropriate for green-field projects. In this approach, the total flare design load is established by adding all individual loads; assuming that peak flow from all sources will occur at the same time resulting in overdesign of flare system. A dynamic simulation model was developed to analyze the behavior of flare system during emergency relief scenario incorporating the actual volumes of Flare KOD, sub/main flare header and actual opening time of blowdown valves. The dynamic approach accounts for the packing phenomena in the overall flare system network which significantly optimizes the design of flare system and associated equipment. The results of dynamic approach are compared with conservative conventional approach. The study concludes that dynamic approach for flare system design provides more accurate estimation of peak flare load.
{"title":"De-Bottlenecking of Existing Flare System for Facility Up-Gradation using Dynamic Simulation Approach - Case Study","authors":"R. Wasnik, H. Singh, F. Kamal, Oussama Takieddine","doi":"10.2118/192750-ms","DOIUrl":"https://doi.org/10.2118/192750-ms","url":null,"abstract":"\u0000 In today's oil prices scenario, industry's focus is shifting towards Brownfield projects having low CAPEX utilizing existing Oil & Gas assets. Towards this objective, de-bottlenecking of existing flare system becomes inevitable for facilities up-gradation. The spare capacity of existing flare is utilized to accommodate additional relief loads from new facility, thus avoiding installation of new flare. Dynamic simulation approach provides significant advantages over conventional approach in terms of realistic estimation of flare capacity and optimal use of existing plant assets.\u0000 The conventional steady state approach assumptions provide conservative relief loads considering sum of instantaneous peak flows of relieving devices irrespective of their opening time. Flare operations are inherently dynamic in nature and dynamic simulations provide more realistic relief loads and presents optimal approach to de-bottlenecking of existing flare system.\u0000 Latest API approach to determine relief rate based on Fire Response Analysis using vessel rupture acceptance criteria also provides additional benefits in terms of relief load optimization as compared to conventional API approach to reduce the system pressure to 50% or 100 Psig in 15 minutes.\u0000 Dynamic approach also accounts for the packing effect in flare network, system operating pressure at which blow down will initiate and sequential opening of blow down valves for each isolatable section. Thus, dynamic approach provides better understanding of the dynamic behavior during blow down scenario. The flare system of offshore gas processing platform was originally designed based on steady state approach, commonly used being a conservative design which is more appropriate for green-field projects. In this approach, the total flare design load is established by adding all individual loads; assuming that peak flow from all sources will occur at the same time resulting in overdesign of flare system.\u0000 A dynamic simulation model was developed to analyze the behavior of flare system during emergency relief scenario incorporating the actual volumes of Flare KOD, sub/main flare header and actual opening time of blowdown valves. The dynamic approach accounts for the packing phenomena in the overall flare system network which significantly optimizes the design of flare system and associated equipment.\u0000 The results of dynamic approach are compared with conservative conventional approach. The study concludes that dynamic approach for flare system design provides more accurate estimation of peak flare load.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86000659","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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