Shehzad Ahmed, K. Elraies, A. Hanamertani, M. Hashmet, Siti Rohaida M. Shafian, Ivy Chai Ching Hsia
The application of CO2 foam has caught overwhelming attention for fracturing shales. In applications, high foam deterioration and insufficient viscosity at operating conditions are the major concerns associated with foam fracturing process. In this study, polymer-free CO2 foam possessing high stability has been presented through chemical screening and optimization under HPHT conditions. Initial screening was performed by conducting a series of foam stability experiments considering different commercial anionic surfactants, concentration, and foam stabilizer addition using FoamScan instrument. Foam rheology study was then performed by considering the similar investigated factors under fracturing conditions using HTHP foam rheometer. All the tested solutions were prepared in fixed brine salinity and HPAM polymers with different molecular weights were used in evaluation of the performance of the designed polymer-free foam in term of foam strength. In comparison with other types of surfactant, alpha olefin sulfonate (AOS) exhibited the best foam stability and viscosity at testing conditions. The optimum AOS concentration providing the best performance was found to be 5000 ppm and its combination with 5000 ppm of foam booster (betaine) further increased AOS foam longevity. An improved result on foam stability and viscosity was not obtained by increasing surfactant concentration. Results on foam rheology reveals that CO2 foam generated in the presence of different molecular weight classical HPAM polymers could not provide significant increment in foam viscosity under experimental conditions. It was observed that these types of polymer underwent degradation due to some unfavorable mechanisms which will be expected to negatively affect its performance during fracturing process. On the other hand, polymer-free CO2 foam was found to produce a higher stability and relatively equally high viscosity compared to polymer-stabilied CO2 foam without experiencing degradation at high pressure and temperature conditions. Therefore, based on this study, it is recommended to use polymer-free foam for fracturing shales application. The use of formulated polymer-free CO2 foam which has high stability and viscosity will lead to improved fracture cleanup, minimized formation damage and pore plugging, and efficient proppant placement which will ultimately enhance gas recovery from unconventional shales.
{"title":"Investigation of Carbon Dioxide Foam Performance Utilizing Different Additives for Fracturing Unconventional Shales","authors":"Shehzad Ahmed, K. Elraies, A. Hanamertani, M. Hashmet, Siti Rohaida M. Shafian, Ivy Chai Ching Hsia","doi":"10.2118/197964-ms","DOIUrl":"https://doi.org/10.2118/197964-ms","url":null,"abstract":"\u0000 The application of CO2 foam has caught overwhelming attention for fracturing shales. In applications, high foam deterioration and insufficient viscosity at operating conditions are the major concerns associated with foam fracturing process. In this study, polymer-free CO2 foam possessing high stability has been presented through chemical screening and optimization under HPHT conditions. Initial screening was performed by conducting a series of foam stability experiments considering different commercial anionic surfactants, concentration, and foam stabilizer addition using FoamScan instrument. Foam rheology study was then performed by considering the similar investigated factors under fracturing conditions using HTHP foam rheometer. All the tested solutions were prepared in fixed brine salinity and HPAM polymers with different molecular weights were used in evaluation of the performance of the designed polymer-free foam in term of foam strength. In comparison with other types of surfactant, alpha olefin sulfonate (AOS) exhibited the best foam stability and viscosity at testing conditions. The optimum AOS concentration providing the best performance was found to be 5000 ppm and its combination with 5000 ppm of foam booster (betaine) further increased AOS foam longevity. An improved result on foam stability and viscosity was not obtained by increasing surfactant concentration. Results on foam rheology reveals that CO2 foam generated in the presence of different molecular weight classical HPAM polymers could not provide significant increment in foam viscosity under experimental conditions. It was observed that these types of polymer underwent degradation due to some unfavorable mechanisms which will be expected to negatively affect its performance during fracturing process. On the other hand, polymer-free CO2 foam was found to produce a higher stability and relatively equally high viscosity compared to polymer-stabilied CO2 foam without experiencing degradation at high pressure and temperature conditions. Therefore, based on this study, it is recommended to use polymer-free foam for fracturing shales application. The use of formulated polymer-free CO2 foam which has high stability and viscosity will lead to improved fracture cleanup, minimized formation damage and pore plugging, and efficient proppant placement which will ultimately enhance gas recovery from unconventional shales.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84851475","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}
K. Deshpande, M. A. Celigueta, S. Latorre, E. Oñate, P. Naphade
Cuttings transport and hole-cleaning is a challenging issue associated with the efficiency of wellbore hydraulics and drilling operation. Traditional methods used to understand hole cleaning problems are based on field observations and extensive flow loop testing to formulate empirical correlations and mechanistic models. The focus of this study is to create digital twin utilizing advanced simulation techniques that provides better insight for cuttings transport and hole-cleaning. This study explores the use of Eulerian-Lagrangian based numerical techniques to estimate critical flow rate needed for efficient hole cleaning. Digital twin for the cuttings transport is formulated utilizing three dimensional Navier stokes equations employing combination of Eulerian and lagrangian approaches to model the drilling mud flow and cuttings interaction with the drilling mud, wellbore walls and between cuttings themselves. One of the important model to estimate the drag force on cuttings is modified for non-spherical cuttings shape coupled with non-newtonian Herschel Bulkley behavior of the drilling mud in this work. The influence of important parameters, such as fluid rheology, rotation of drill-string, and inclination of wellbore on the hole-cleaning process is investigated. Digital solutions are compared against the published data for Newtonian and non-Newtonian drilling fluids under different wellbore configurations. The advanced computational simulation involving novel drag force correlation and unique combination of numerical methods allowed to create digital twin for cuttings transport process accurately. The numerical strategy utilizing modified drag law showed a very good match with experimental results for straight vertical wellbore, the cuttings transport velocity estimated by digital solutions was within 5% difference of experimental results. Further upon validation, numerical results are successfully computed for drill -string rotation effects which clearly showed physics of cuttings transported efficiently with added energy due to rotation. The phenomenon of cuttings bed sliding in inclined and horizontal wellbores is also correctly simulated with the proposed drag law and numerical methods. The proposed methodology works without any issues with high concentration of cuttings and provides detailed insight into cuttings flow path and effect of various operational parameters on hole cleaning. Advanced computational simulations and modification of drag force law assisted in formulating digital twin that provided excellent insights in understanding effects of operational parameters for efficient hole cleaning.
{"title":"Digital Solutions Using Advanced Computational Techniques to Simulate Hole Cleaning","authors":"K. Deshpande, M. A. Celigueta, S. Latorre, E. Oñate, P. Naphade","doi":"10.2118/197864-ms","DOIUrl":"https://doi.org/10.2118/197864-ms","url":null,"abstract":"\u0000 Cuttings transport and hole-cleaning is a challenging issue associated with the efficiency of wellbore hydraulics and drilling operation. Traditional methods used to understand hole cleaning problems are based on field observations and extensive flow loop testing to formulate empirical correlations and mechanistic models. The focus of this study is to create digital twin utilizing advanced simulation techniques that provides better insight for cuttings transport and hole-cleaning. This study explores the use of Eulerian-Lagrangian based numerical techniques to estimate critical flow rate needed for efficient hole cleaning. Digital twin for the cuttings transport is formulated utilizing three dimensional Navier stokes equations employing combination of Eulerian and lagrangian approaches to model the drilling mud flow and cuttings interaction with the drilling mud, wellbore walls and between cuttings themselves. One of the important model to estimate the drag force on cuttings is modified for non-spherical cuttings shape coupled with non-newtonian Herschel Bulkley behavior of the drilling mud in this work. The influence of important parameters, such as fluid rheology, rotation of drill-string, and inclination of wellbore on the hole-cleaning process is investigated. Digital solutions are compared against the published data for Newtonian and non-Newtonian drilling fluids under different wellbore configurations. The advanced computational simulation involving novel drag force correlation and unique combination of numerical methods allowed to create digital twin for cuttings transport process accurately. The numerical strategy utilizing modified drag law showed a very good match with experimental results for straight vertical wellbore, the cuttings transport velocity estimated by digital solutions was within 5% difference of experimental results. Further upon validation, numerical results are successfully computed for drill -string rotation effects which clearly showed physics of cuttings transported efficiently with added energy due to rotation. The phenomenon of cuttings bed sliding in inclined and horizontal wellbores is also correctly simulated with the proposed drag law and numerical methods. The proposed methodology works without any issues with high concentration of cuttings and provides detailed insight into cuttings flow path and effect of various operational parameters on hole cleaning. Advanced computational simulations and modification of drag force law assisted in formulating digital twin that provided excellent insights in understanding effects of operational parameters for efficient hole cleaning.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"65 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90157972","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}
F. Hollaender, Y. Shumakov, Ozgur Karacali, B. Theuveny
Today many well test operations are performed in frontier environments targeting high potential oil and gas reservoirs or using high deliverability horizontal wells. Such highly productive wells cannot be dynamically evaluated to acquire representative reservoir data by small-scale flow tests. High flow rate well tests are introducing a set of unique challenges that need to be addressed at the design stage of the test, each requiring an appropriate surface well test spread, DST string as well as job operation procedures and equipment planning. Currently, well tests aiming at achieving very high flow rates are often designed and executed on a case-by-case basis, and there are no practical recommendations available that would summarise the well testing experience in such environments and guide the operator through the process to efficiently plan the well test operations. Well test operations are inherently challenging operations owing to the requirements for well control, accurate data acquisition, and the safe handling and disposal of produced fluids (hydrocarbons, completion brine, water, and solids), concerns are especially acute when considering high flow rates. Several past experiences have clearly shown limitations when trying to achieve high flow rates using conventional approaches and standard well test equipment. Concerns range from equipment failure and operational issues to poor interpretability of acquired data from those tests, increasing the total costs of such well tests or in extreme cases leading to severe HSE incidents. Enhancements in well testing equipment such as new generation well test separators equipped with high-range Coriolis mass flow meters or new generation burners, combined with fit-for-purpose well testing techniques make it possible to overcome these challenges. This paper will summarise the results and lessons learned from high flow rate well test operations performed around the globe on vertical and horizontal wells, in oil and gas reservoirs. The paper provides practical recommendations supported by a series of case studies from multiple oil and gas fields. The paper also describes a comprehensive list of challenges associated with high rate well test operations that can support successful operations design. Recipes for success are provided to ensure that safe operation can be performed in challenging environments.
{"title":"Well Testing to Full Potential: Lessons Learned and Best Practices for High Rate Wells","authors":"F. Hollaender, Y. Shumakov, Ozgur Karacali, B. Theuveny","doi":"10.2118/197754-ms","DOIUrl":"https://doi.org/10.2118/197754-ms","url":null,"abstract":"\u0000 Today many well test operations are performed in frontier environments targeting high potential oil and gas reservoirs or using high deliverability horizontal wells. Such highly productive wells cannot be dynamically evaluated to acquire representative reservoir data by small-scale flow tests.\u0000 High flow rate well tests are introducing a set of unique challenges that need to be addressed at the design stage of the test, each requiring an appropriate surface well test spread, DST string as well as job operation procedures and equipment planning. Currently, well tests aiming at achieving very high flow rates are often designed and executed on a case-by-case basis, and there are no practical recommendations available that would summarise the well testing experience in such environments and guide the operator through the process to efficiently plan the well test operations.\u0000 Well test operations are inherently challenging operations owing to the requirements for well control, accurate data acquisition, and the safe handling and disposal of produced fluids (hydrocarbons, completion brine, water, and solids), concerns are especially acute when considering high flow rates. Several past experiences have clearly shown limitations when trying to achieve high flow rates using conventional approaches and standard well test equipment.\u0000 Concerns range from equipment failure and operational issues to poor interpretability of acquired data from those tests, increasing the total costs of such well tests or in extreme cases leading to severe HSE incidents. Enhancements in well testing equipment such as new generation well test separators equipped with high-range Coriolis mass flow meters or new generation burners, combined with fit-for-purpose well testing techniques make it possible to overcome these challenges.\u0000 This paper will summarise the results and lessons learned from high flow rate well test operations performed around the globe on vertical and horizontal wells, in oil and gas reservoirs. The paper provides practical recommendations supported by a series of case studies from multiple oil and gas fields. The paper also describes a comprehensive list of challenges associated with high rate well test operations that can support successful operations design. Recipes for success are provided to ensure that safe operation can be performed in challenging environments.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"91 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78874854","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}
Abdulaziz Ellafi, H. Jabbari, M. B. Geri, Ethar H. K. Alkamil
In unconventional reservoirs, such as Bakken Fm, the stimulation application is the required method to develop and produce economically from this vast reserve. However, the production process is still only through primary depletion mechanism with low recovery factor in ranging of 3-5% due to sharp decline in oil production by depletion in natural fracture networks as well as unsuccessful implementation hydraulic fracturing design. This paper aims to investigate the application of HVFRs with surfactant in high TDS condition to enhance Bakken oil wells production performance using an integral methodology between 3D/2D Pseudo hydraulic fracturing simulator and numerical reservoir simulation. Four types of fracturing fluids as follows: Linear Gel, HVFR-A (mixed with freshwater), HVFR-B (mixed with produced water plus surfactant as additives), and HVFR-C (mixed with produced water) were tested using an integral approach. The workflow in this paper was started by modeling the optimal fracture half-length using 2D/PKN model based on the slurry volume per stage. As a next step, the optimum pump schedule was created using 3D Pseudo hydraulic fracturing simulator. Furthermore, the sensitivity analysis was performed on HVFR-B at different pump rate, final proppant concentration, and proppant size to investigate the proppant transport and production performance. Finally, reservoir simulation tool was utilized to investigate the changing in fracture parameters and evaluating the Bakken oil production. The results showed that HVFRs with surfactant is the optimum hydraulic fracture fluids that showed better performance in proppant transport, which responded by high fracture capability to improve oil production. The findings can be applied and compared to other unconventional shale plays, such as Eagle Ford and Permian Basin.
{"title":"Can HVFRs Increase the Oil Recovery in Hydraulic Fractures Applications?","authors":"Abdulaziz Ellafi, H. Jabbari, M. B. Geri, Ethar H. K. Alkamil","doi":"10.2118/197744-ms","DOIUrl":"https://doi.org/10.2118/197744-ms","url":null,"abstract":"\u0000 In unconventional reservoirs, such as Bakken Fm, the stimulation application is the required method to develop and produce economically from this vast reserve. However, the production process is still only through primary depletion mechanism with low recovery factor in ranging of 3-5% due to sharp decline in oil production by depletion in natural fracture networks as well as unsuccessful implementation hydraulic fracturing design. This paper aims to investigate the application of HVFRs with surfactant in high TDS condition to enhance Bakken oil wells production performance using an integral methodology between 3D/2D Pseudo hydraulic fracturing simulator and numerical reservoir simulation. Four types of fracturing fluids as follows: Linear Gel, HVFR-A (mixed with freshwater), HVFR-B (mixed with produced water plus surfactant as additives), and HVFR-C (mixed with produced water) were tested using an integral approach. The workflow in this paper was started by modeling the optimal fracture half-length using 2D/PKN model based on the slurry volume per stage. As a next step, the optimum pump schedule was created using 3D Pseudo hydraulic fracturing simulator. Furthermore, the sensitivity analysis was performed on HVFR-B at different pump rate, final proppant concentration, and proppant size to investigate the proppant transport and production performance. Finally, reservoir simulation tool was utilized to investigate the changing in fracture parameters and evaluating the Bakken oil production. The results showed that HVFRs with surfactant is the optimum hydraulic fracture fluids that showed better performance in proppant transport, which responded by high fracture capability to improve oil production. The findings can be applied and compared to other unconventional shale plays, such as Eagle Ford and Permian Basin.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84772478","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}
Maha Al Shehhi, S. Ameri, Ayoub Hadj-moussa, M. Saleh
This paper presents the novel approach used in drilling, running liner and cementing a development well across multiple reservoir with high pore pressure heterogeneity that has historically caused drilling hazards like differential stuck pipe, losses, well control and slow rate of penetrations. Having depleted reservoirs and high-pressure reservoirs in the same hole section of well-A dictates that the mud weight must be higher than the higher reservoir pressure, which puts high differential pressure on the depleted reservoir and causes differential stuck pipe and losses. The uncertainty in determining the pore pressure adds another challenge as the mud weight must be higher than the expected pore pressure. Managed Pressure Drilling (MPD) addresses these challenges by enabling determining the pore pressure while drilling and adjusting the Equivalent Circulation Density (ECD) to be with the minimum overbalance. MPD allowed drilling the section with (12.0 ppg) mud weight instead of the conventional mud weight (15.7 ppg). This has reduced the differential pressure between the depleted formation and the other formations significantly and enhanced the rate of penetration while balancing the well. It also proved that verifying the well's prognosis for pressure is essential in avoiding drilling hazards. Constant Bottom Hole Pressure (CBHP) mode of MPD was used to maintain the same ECD while drilling and connection to avoid well influx during pumps off events by compensating the annular friction pressure loss by surface back pressure. MPD was utilized too in running the 7″ liner and cementing it as a guarantee if the mud weight was too low to stabilize the well. The operation was carried out without safety or quality issue. The MPD system performance was with zero nonproductive time and the hole section was drilled shoe-to-shoe without any change the Rotating Control Device (RCD). This application showed an alternative preventive solution to differentially stuck pipe instead of the reactive one. The approach explained in this paper is the first of its kind in ADNOC Onshore field. It involved altering the mud weight program strategically for more adaptive approach in dealing with drilling hazards like differential stuck pipe, losses and well control. The scheme involving MPD for running liner and cementing is the first ever in United Arab Emirates.
{"title":"Managed Pressure Drilling Tackles Pore Pressure Uncertainty While Drilling, Running Liner, and Cementing Across Multiple and Heterogonic Layered Reservoirs for the First Time in the United Arab Emirates","authors":"Maha Al Shehhi, S. Ameri, Ayoub Hadj-moussa, M. Saleh","doi":"10.2118/197273-ms","DOIUrl":"https://doi.org/10.2118/197273-ms","url":null,"abstract":"\u0000 This paper presents the novel approach used in drilling, running liner and cementing a development well across multiple reservoir with high pore pressure heterogeneity that has historically caused drilling hazards like differential stuck pipe, losses, well control and slow rate of penetrations.\u0000 Having depleted reservoirs and high-pressure reservoirs in the same hole section of well-A dictates that the mud weight must be higher than the higher reservoir pressure, which puts high differential pressure on the depleted reservoir and causes differential stuck pipe and losses. The uncertainty in determining the pore pressure adds another challenge as the mud weight must be higher than the expected pore pressure. Managed Pressure Drilling (MPD) addresses these challenges by enabling determining the pore pressure while drilling and adjusting the Equivalent Circulation Density (ECD) to be with the minimum overbalance.\u0000 MPD allowed drilling the section with (12.0 ppg) mud weight instead of the conventional mud weight (15.7 ppg). This has reduced the differential pressure between the depleted formation and the other formations significantly and enhanced the rate of penetration while balancing the well. It also proved that verifying the well's prognosis for pressure is essential in avoiding drilling hazards. Constant Bottom Hole Pressure (CBHP) mode of MPD was used to maintain the same ECD while drilling and connection to avoid well influx during pumps off events by compensating the annular friction pressure loss by surface back pressure. MPD was utilized too in running the 7″ liner and cementing it as a guarantee if the mud weight was too low to stabilize the well. The operation was carried out without safety or quality issue. The MPD system performance was with zero nonproductive time and the hole section was drilled shoe-to-shoe without any change the Rotating Control Device (RCD). This application showed an alternative preventive solution to differentially stuck pipe instead of the reactive one.\u0000 The approach explained in this paper is the first of its kind in ADNOC Onshore field. It involved altering the mud weight program strategically for more adaptive approach in dealing with drilling hazards like differential stuck pipe, losses and well control. The scheme involving MPD for running liner and cementing is the first ever in United Arab Emirates.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"55 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74621645","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}
Production of Oil, Gas and Petrochemical from production units is becoming very competitive every day. As products are sold in open market, production cost drives an organization's profitability. To keep a plant available for production as much as possible, Asset Performance Management (APM) or Asset Integrity Management (AIM)is the key. Risk based inspection (RBI) is a decision making tool that deals with integrity management of static equipment and piping through focus on prioritizing inspection based on the risk. Review of published guidelines for RBI such as API RP 580/581, ASME PCC3, DNV-RP-G101, EN 16991 etc., suggests that they provide either oversimplified or complex explanations which makes it difficult for beginners to grasp all the aspects that are critical for a successful RBI project. Therefore, this paper is aimed to provide and discuss the essential elements for effective RBI implementation project in a simplified way. RBI project can be divided into four major phases i.e project initiation and pre-requisites, workshops & trainings, RBI analysis phase and post RBI actions. Each of these stages is discussed with details in this paper. An overview of successful RBI program used within the industry and from the ADNOC LNG RBI implementation experience, is provided with details. Project management approach for RBI program implementation is conveyed by dividing project into different phases and highlighting the inputs/outputs and activities for each phase. Objectives, time and resources such as data and personnel required, software features that are essential, project planning and monitoring are provided. RBI program implemented efficiently in accordance with suggested plan, results in an overall optimization of inspection for static equipment/piping while maintaining their integrity as part of a broader APM or AIM strategy.
生产单位的石油、天然气和石化产品的竞争日益激烈。当产品在公开市场上销售时，生产成本驱动组织的盈利能力。为了使工厂尽可能多地用于生产，资产绩效管理(APM)或资产完整性管理(AIM)是关键。基于风险的检查(RBI)是一种决策工具，通过关注基于风险的检查优先级来处理静态设备和管道的完整性管理。回顾已发布的RBI指南，如API RP 580/581, ASME PCC3, DNV-RP-G101, EN 16991等，表明它们提供的解释要么过于简单，要么过于复杂，这使得初学者很难掌握成功RBI项目的所有关键方面。因此，本文旨在以一种简化的方式提供和讨论有效的RBI实施项目的基本要素。RBI项目可以分为四个主要阶段，即项目启动和先决条件，研讨会和培训，RBI分析阶段和后RBI行动。本文详细讨论了每一个阶段。详细介绍了行业内成功使用的RBI计划以及ADNOC LNG RBI实施经验。RBI计划实施的项目管理方法是通过将项目划分为不同的阶段并突出每个阶段的输入/输出和活动来传达的。提供目标、时间和资源，如所需的数据和人员、必要的软件特性、项目计划和监测。RBI计划按照建议的计划有效实施，使静态设备/管道的检查得到全面优化，同时保持其完整性，作为更广泛的APM或AIM战略的一部分。
{"title":"Implementing a Successful Risk Based Inspection Program","authors":"Asad Ali, H. Sabry","doi":"10.2118/197790-ms","DOIUrl":"https://doi.org/10.2118/197790-ms","url":null,"abstract":"\u0000 Production of Oil, Gas and Petrochemical from production units is becoming very competitive every day. As products are sold in open market, production cost drives an organization's profitability. To keep a plant available for production as much as possible, Asset Performance Management (APM) or Asset Integrity Management (AIM)is the key. Risk based inspection (RBI) is a decision making tool that deals with integrity management of static equipment and piping through focus on prioritizing inspection based on the risk.\u0000 Review of published guidelines for RBI such as API RP 580/581, ASME PCC3, DNV-RP-G101, EN 16991 etc., suggests that they provide either oversimplified or complex explanations which makes it difficult for beginners to grasp all the aspects that are critical for a successful RBI project. Therefore, this paper is aimed to provide and discuss the essential elements for effective RBI implementation project in a simplified way. RBI project can be divided into four major phases i.e project initiation and pre-requisites, workshops & trainings, RBI analysis phase and post RBI actions. Each of these stages is discussed with details in this paper.\u0000 An overview of successful RBI program used within the industry and from the ADNOC LNG RBI implementation experience, is provided with details. Project management approach for RBI program implementation is conveyed by dividing project into different phases and highlighting the inputs/outputs and activities for each phase. Objectives, time and resources such as data and personnel required, software features that are essential, project planning and monitoring are provided.\u0000 RBI program implemented efficiently in accordance with suggested plan, results in an overall optimization of inspection for static equipment/piping while maintaining their integrity as part of a broader APM or AIM strategy.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85711290","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}
Important hydrocarbon accumulations occur in tight rocks in Colombian areas. Those tight reservoirs consist of clean sandstones with matrix porosities in the 3% to 4% range, relatively complex mineralogy and naturally fractured. The success of achieving a representative formation evaluation relies on obtaining accurate porosity, oil, gas, water saturations, natural fractures detection and good estimates on reservoir permeability. Resistivity-based approaches are difficult to apply since reservoir conductivity is not only influenced by fluid type, but also by salinity (typically low in our reservoirs), variable tortuosity (mostly high in the matrix and very low in fractures) and very high formation resistivity (above 1,000 ohms.m). In addition, a combination of low pores volumes and a matrix not properly assessed, leads to high errors in the porosity determination with conventional logs (in a 3 – 4 p.u. reservoir, the porosity error computation can be as high as 50%). Uncertainties in porosity estimates also translates to uncertainties during saturation assessment. Further challenges are found when attempting the saturation computation from resistivity logs. The tight sands are drilled with Oil Based Muds, creating a logging environment where only induction logs are possible. However, since the resistivity range in these rocks is above 1000 ohm.m range, the induction measurements are out of range in many of the target zones. Alternative formation evaluation methods for assessing fluids saturations, like magnetic resonance, sigma and carbon-oxygen logs cannot be applied below 10 porosity units; whereas dielectric measurements strongly depend on accurate porosity computations for deriving the hydrocarbon volume. Some of these reservoirs, are also deep (in the 17,000 ft range) and close to foothills, where wellbore stability issues and narrow mud weight windows used for drilling, translates into higher risks for open-hole logging via logging while drilling or wireline conveyance, all of it detrimental to data acquisition in open hole. Therefore, the case studies presented in this paper were assessed in cased hole conditions. In this paper, we present a solution that cover tight matrix and natural fractures assessment, at a level not previously achieved. At the tight matrix level, we carry out advanced nuclear spectroscopy with a new pulsed neutron device, that carry out simultaneous time domain and energy domain measurements. A new resistivity and salinity independent methodology for obtaining Gas saturation from a new measurement in the industry known as "Fast Neutron Cross Section" (FNXS), oil saturation from the total organic carbon (TOC) log, mineral volumes solved from formation elemental concentrations from energy domain, and porosity from hydrogen index obtained from the spectroscopy time domain, is presented. At natural fracture level, we make use of a Borehole Acoustic Reflection Service for deep natural fracture detection and spatial o
{"title":"Cased Hole Solution with Fast Neutrons and Sonic Reflective Waves in Tight Reservoirs","authors":"U. Bustos, C. Moya, D. Rose, T. Zhou, G. Martinez","doi":"10.2118/197423-ms","DOIUrl":"https://doi.org/10.2118/197423-ms","url":null,"abstract":"\u0000 Important hydrocarbon accumulations occur in tight rocks in Colombian areas. Those tight reservoirs consist of clean sandstones with matrix porosities in the 3% to 4% range, relatively complex mineralogy and naturally fractured. The success of achieving a representative formation evaluation relies on obtaining accurate porosity, oil, gas, water saturations, natural fractures detection and good estimates on reservoir permeability. Resistivity-based approaches are difficult to apply since reservoir conductivity is not only influenced by fluid type, but also by salinity (typically low in our reservoirs), variable tortuosity (mostly high in the matrix and very low in fractures) and very high formation resistivity (above 1,000 ohms.m). In addition, a combination of low pores volumes and a matrix not properly assessed, leads to high errors in the porosity determination with conventional logs (in a 3 – 4 p.u. reservoir, the porosity error computation can be as high as 50%). Uncertainties in porosity estimates also translates to uncertainties during saturation assessment.\u0000 Further challenges are found when attempting the saturation computation from resistivity logs. The tight sands are drilled with Oil Based Muds, creating a logging environment where only induction logs are possible. However, since the resistivity range in these rocks is above 1000 ohm.m range, the induction measurements are out of range in many of the target zones. Alternative formation evaluation methods for assessing fluids saturations, like magnetic resonance, sigma and carbon-oxygen logs cannot be applied below 10 porosity units; whereas dielectric measurements strongly depend on accurate porosity computations for deriving the hydrocarbon volume.\u0000 Some of these reservoirs, are also deep (in the 17,000 ft range) and close to foothills, where wellbore stability issues and narrow mud weight windows used for drilling, translates into higher risks for open-hole logging via logging while drilling or wireline conveyance, all of it detrimental to data acquisition in open hole. Therefore, the case studies presented in this paper were assessed in cased hole conditions.\u0000 In this paper, we present a solution that cover tight matrix and natural fractures assessment, at a level not previously achieved. At the tight matrix level, we carry out advanced nuclear spectroscopy with a new pulsed neutron device, that carry out simultaneous time domain and energy domain measurements. A new resistivity and salinity independent methodology for obtaining Gas saturation from a new measurement in the industry known as \"Fast Neutron Cross Section\" (FNXS), oil saturation from the total organic carbon (TOC) log, mineral volumes solved from formation elemental concentrations from energy domain, and porosity from hydrogen index obtained from the spectroscopy time domain, is presented. At natural fracture level, we make use of a Borehole Acoustic Reflection Service for deep natural fracture detection and spatial o","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83493779","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Oil and Gas, Petroleum Refining Industry is undergroing through significant Business Challenges, Transformation and Consolidation. Refinery Business Economics has been encountering increased challenges due to significant variations in the market dynamics. Refining Optimization has acquired renewed importance in the past decade and optimization of the existing facilities has become a key component in the overall Business Strategy. Operational Excellence forms the necessary attribute for Optimal Business Performance of the Progressive Companies. Operational Excellence and Business Excellence are the key focus areas for Petroleum Refining Industry in the Middle East and Other Regions. Operational Excellence and Business Excellence requires best in class performance in all the functional areas of relevance to the Business. Operational Excellence and Business Excellence are closely inter- related and complement one another towards superior Business Performance. Operational Excellence Groups in the company deal with activities that would help to inculcate culture of excellence and help in the effective implementation of continuous improvement activities across the company facilities. Periodic Assessment of Operational Excellence is extremely important for identifying the status and take necessary corrective measures /additional measures towards continuous improvement. ADNOC Refining has been involved in Operational Excellence activities and Business Excellence activities for the past two decades with and without the involvement of external consultants. This paper deals with key aspects of Operational Excellence review and methodology of systematic implementation, key challenges, and experiences of first of its kind simultaneous implementation across ADNOC Refining Operating Facilities.
{"title":"Operational Excellence Review through Self-Assessment","authors":"Srinivas Badithela, Mohamed Ali Al-Haddadi","doi":"10.2118/197313-ms","DOIUrl":"https://doi.org/10.2118/197313-ms","url":null,"abstract":"\u0000 Oil and Gas, Petroleum Refining Industry is undergroing through significant Business Challenges, Transformation and Consolidation. Refinery Business Economics has been encountering increased challenges due to significant variations in the market dynamics. Refining Optimization has acquired renewed importance in the past decade and optimization of the existing facilities has become a key component in the overall Business Strategy. Operational Excellence forms the necessary attribute for Optimal Business Performance of the Progressive Companies. Operational Excellence and Business Excellence are the key focus areas for Petroleum Refining Industry in the Middle East and Other Regions. Operational Excellence and Business Excellence requires best in class performance in all the functional areas of relevance to the Business. Operational Excellence and Business Excellence are closely inter- related and complement one another towards superior Business Performance. Operational Excellence Groups in the company deal with activities that would help to inculcate culture of excellence and help in the effective implementation of continuous improvement activities across the company facilities. Periodic Assessment of Operational Excellence is extremely important for identifying the status and take necessary corrective measures /additional measures towards continuous improvement. ADNOC Refining has been involved in Operational Excellence activities and Business Excellence activities for the past two decades with and without the involvement of external consultants. This paper deals with key aspects of Operational Excellence review and methodology of systematic implementation, key challenges, and experiences of first of its kind simultaneous implementation across ADNOC Refining Operating Facilities.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84082970","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}
Muhammad Tayab, S. Valappil, Vishal Shah, Takhir Azhibekov, M. Zeinati, Mohammed Al Ameri, Fatima Al-Hameli
Over the last 10 years, Oil & Gas operations have come under tremendous pressures due to increasing production demands and economic conditions, demanding higher performance and venturing into technically challenging operating conditions. Operating with aging facilities in harsh environmental conditions and higher crew turnaround, have resulted in higher number of serious incidents. Prevention of incidents remains high on the agenda of oil & gas companies and focus is placed on incident investigations to identify root causes of incidents and development of corrective actions. However, repetition of incidents with similar findings and causes have been observed, raising concerns if right root causes were identified and focused corrective actions were identified and/or implemented. An extended analysis of over one thousand (1000) incidents was conducted to assess degree of repetition of causes and regrouping of causes to assess linkage of human factors with organizational behaviours. It was found that 31% of incidents were triggered by human errors & mistakes whilst 27% were attributed to violations. All violations were deemed as intentional & routine and further investigation was not undertaken. Management Supervion & Employees Leadership was identified a leading root cause category of incidents and this category contributed 20% of incidents followed by Work Planning (18%) and behaviour (12%). 55 % of incidents were caused by human factors and hauman factors were triggered by errors and mistakes rather than violations. Often efforts are exerted to to influence individual's behaviour however human attitude (cognitive, emotional and commitment) is overlooked as linkage between attitude change leading to behavior change, not fully explored. However, linkage from behavior change to attitude change is much stronger. If worker consciously change their behavior, it requires re adjustment of associated attitudes to align with the new behavior. Positive reinforcement is an effective tool to influence individual's behaviour. If discipline and punishment are used to discourage unsafe behavior, the intended results are not achieved (e.g., incident or near miss are not reported for fear of sanctions). Assessment of non-compliant behaviors (Violations, mistakes and errors) & conditions and factors influencing such behaviors are often not evaluated and focused action plans to address abilities and motivations with due consideration to isolated or systemic conditions are instrumental in preventing incicidents.
{"title":"Sequential Failures in Incident Investigation Process Hindering Prevention of Incidents","authors":"Muhammad Tayab, S. Valappil, Vishal Shah, Takhir Azhibekov, M. Zeinati, Mohammed Al Ameri, Fatima Al-Hameli","doi":"10.2118/197163-ms","DOIUrl":"https://doi.org/10.2118/197163-ms","url":null,"abstract":"\u0000 Over the last 10 years, Oil & Gas operations have come under tremendous pressures due to increasing production demands and economic conditions, demanding higher performance and venturing into technically challenging operating conditions. Operating with aging facilities in harsh environmental conditions and higher crew turnaround, have resulted in higher number of serious incidents. Prevention of incidents remains high on the agenda of oil & gas companies and focus is placed on incident investigations to identify root causes of incidents and development of corrective actions. However, repetition of incidents with similar findings and causes have been observed, raising concerns if right root causes were identified and focused corrective actions were identified and/or implemented.\u0000 An extended analysis of over one thousand (1000) incidents was conducted to assess degree of repetition of causes and regrouping of causes to assess linkage of human factors with organizational behaviours. It was found that 31% of incidents were triggered by human errors & mistakes whilst 27% were attributed to violations. All violations were deemed as intentional & routine and further investigation was not undertaken. Management Supervion & Employees Leadership was identified a leading root cause category of incidents and this category contributed 20% of incidents followed by Work Planning (18%) and behaviour (12%). 55 % of incidents were caused by human factors and hauman factors were triggered by errors and mistakes rather than violations.\u0000 Often efforts are exerted to to influence individual's behaviour however human attitude (cognitive, emotional and commitment) is overlooked as linkage between attitude change leading to behavior change, not fully explored. However, linkage from behavior change to attitude change is much stronger. If worker consciously change their behavior, it requires re adjustment of associated attitudes to align with the new behavior. Positive reinforcement is an effective tool to influence individual's behaviour. If discipline and punishment are used to discourage unsafe behavior, the intended results are not achieved (e.g., incident or near miss are not reported for fear of sanctions).\u0000 Assessment of non-compliant behaviors (Violations, mistakes and errors) & conditions and factors influencing such behaviors are often not evaluated and focused action plans to address abilities and motivations with due consideration to isolated or systemic conditions are instrumental in preventing incicidents.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86763101","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}
ENSURING IMPROVED ASSET INTEGRITY by Realtime Corrosion Monitoring and Steam Trap Monitoring Monitoring of corrosion in a process pipelines have always been of paramount importance to ensure the integrity of plant assets. Similarly, steam traps play a very important role in ensuring steam quality, thereby the integrity of critical assets in the plant. It is common observation that many of the steamtraps become non-functional over a period of time and, more importantly, dangerously go unnoticed. While these are vital in ensuring asset integrity, and need continuous monitoring, it is also a highly demanding and challenging activity in the field, and a dream of many Integrity engineers to perform such asset monitoring remotely, that too, in realtime. Many vendors have been researching on this, and focusing on devising improved technology to ease the burden on such asset monitoring. This paper intends to touch upon these two aspects of monitoring Asset Integrity – Realtime Corrosion monitoring and Realtime Steam Trap monitoring – as implemented in ADNOC-LNG. The paper shall highlight the importance of digitalization in the Asset Integrity Management - Pipeline Corrosion and Steam Trap monitoring - by means of implementing wireless technology and making the data available in remote workstations in realtime. Topics covered: Corrosion Monitoring: to move ahead from the conventional Corrosion management to the Wireless Ultrasonic Thickness gauging technology Steam Trap Monitoring: to remotely monitor the healthiness of Steam Traps with a combination acoustic and temperature instruments. Corrosion Monitoring: The installation at ADNOC-LNG covers 20 locations in OAG unit (Offshore Associated Gas unit, which has been identified as highly corrosion prone). The procedure involves installing UT sensors at the identified CMLs (Corrosion Monitoring Locations). These are easily installable onto the piping, and each sensor has a measurement footprint of about 1-2 cm2, which is similar to the manual ultrasound inspection method. The technology of ultrasound is well proven and has been used by Integrity engineers for manual inspections. These sensors employ wireless communication, and are powered by battery packs, which last through turnarounds. Doing away with the needs of power and signal cable, simplifies the installation process. Steam trap monitoring system (20 locations identified in LNG Train-3 Utilities) also employs wireless acoustic and temperature sensors, which are installed on the steam trap piping. From the acoustics and based on the skin temperature measurements, the system identifies the health of the steam traps and determines which are Failed shut, or blow through. Corrosion Sensors: These UT sensors continue to give the wall thickness measurements of the exactly same point, over a period of time, which can help analyze the early onset of corrosion; unlike the manual UT measurements, where the repeatability and reproducibi
{"title":"Digitalize Asset Integrity Management by Remote Monitoring","authors":"Mohamed Sahid","doi":"10.2118/197168-ms","DOIUrl":"https://doi.org/10.2118/197168-ms","url":null,"abstract":"\u0000 \u0000 \u0000 ENSURING IMPROVED ASSET INTEGRITY by Realtime Corrosion Monitoring and Steam Trap Monitoring\u0000 Monitoring of corrosion in a process pipelines have always been of paramount importance to ensure the integrity of plant assets. Similarly, steam traps play a very important role in ensuring steam quality, thereby the integrity of critical assets in the plant. It is common observation that many of the steamtraps become non-functional over a period of time and, more importantly, dangerously go unnoticed. While these are vital in ensuring asset integrity, and need continuous monitoring, it is also a highly demanding and challenging activity in the field, and a dream of many Integrity engineers to perform such asset monitoring remotely, that too, in realtime. Many vendors have been researching on this, and focusing on devising improved technology to ease the burden on such asset monitoring.\u0000 This paper intends to touch upon these two aspects of monitoring Asset Integrity – Realtime Corrosion monitoring and Realtime Steam Trap monitoring – as implemented in ADNOC-LNG. The paper shall highlight the importance of digitalization in the Asset Integrity Management - Pipeline Corrosion and Steam Trap monitoring - by means of implementing wireless technology and making the data available in remote workstations in realtime.\u0000 Topics covered:\u0000 Corrosion Monitoring: to move ahead from the conventional Corrosion management to the Wireless Ultrasonic Thickness gauging technology\u0000 Steam Trap Monitoring: to remotely monitor the healthiness of Steam Traps with a combination acoustic and temperature instruments.\u0000 \u0000 \u0000 \u0000 Corrosion Monitoring: The installation at ADNOC-LNG covers 20 locations in OAG unit (Offshore Associated Gas unit, which has been identified as highly corrosion prone). The procedure involves installing UT sensors at the identified CMLs (Corrosion Monitoring Locations). These are easily installable onto the piping, and each sensor has a measurement footprint of about 1-2 cm2, which is similar to the manual ultrasound inspection method. The technology of ultrasound is well proven and has been used by Integrity engineers for manual inspections. These sensors employ wireless communication, and are powered by battery packs, which last through turnarounds. Doing away with the needs of power and signal cable, simplifies the installation process.\u0000 Steam trap monitoring system (20 locations identified in LNG Train-3 Utilities) also employs wireless acoustic and temperature sensors, which are installed on the steam trap piping. From the acoustics and based on the skin temperature measurements, the system identifies the health of the steam traps and determines which are Failed shut, or blow through.\u0000 \u0000 \u0000 \u0000 Corrosion Sensors: These UT sensors continue to give the wall thickness measurements of the exactly same point, over a period of time, which can help analyze the early onset of corrosion; unlike the manual UT measurements, where the repeatability and reproducibi","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84487715","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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