With many of the offshore platforms around the globe well past their design life, developing targeted and cost-effective approaches to reassess and manage the life extension of these facilities is critical for operators. Although standards such as API RP 2SIM and ISO 19901-9 provide an excellent framework for management of the structural integrity of individual platforms, operators that manage a significant number of facilities need to develop strategies for overseeing the life extension of a fleet of aging multidiscipline assets, with the objective of maximizing return while maintaining an acceptable level of risk. The paper presents a systematic risk matrix based approach to provide a predictive assessment of the residual lives of the offshore facilities using the available design and condition data, re-assessment results based on asset specific or grouped approaches, and existing inspection results and strategies. Weighting of the influence of each parameter, adapted for different asset classes to capture state-of-the-art approaches within each discipline or system, is used to predicted residual life. This method has the ability to handle sparse data and incorporate recent or planned modifications. The increased likelihood of failure with time due to damage or degradation, as well as other threats such as obsolesce, is captured through time dependent factors to provide an estimate of the residual life. The method used provides a flexible assessment of the health and residual life estimates for assets from a sub-system through to a full field perspective based on the existing risk tolerance and management strategies of the operator. This provides operators with a valuable tool to assist in optimizing the life cycle costs for the field. If the overall risk profile is not acceptable, then high level what-if analyses can be performed and incorporated into the risk model to review likelihood or consequence reducing measures as the facilities age. This may include additional assessments (e.g. platform specific ultimate strength or fitness-for-service assessments of major equipment), changes to fabric maintenance or risk based inspection plans, load reductions, upgrading of instrumentation and control systems, implementation of strengthening, modification or repair programs, or decommissioning. Advisian has successfully applied this approach for both offshore and onshore assets. Unlike most life extension programs which are typically limited to a single discipline, this method provides a flexible multidisciplinary approach with the ability to incorporate findings covering topside structures, pipelines, piping, rotating and static equipment, electrical and instrumentation for a whole of field assessment.
随着全球许多海上平台已超过设计寿命，开发有针对性且具有成本效益的方法来重新评估和管理这些设施的寿命延长对运营商来说至关重要。尽管API RP 2SIM和ISO 19901-9等标准为管理单个平台的结构完整性提供了一个很好的框架，但管理大量设施的运营商需要制定策略来监督老化的多学科资产的寿命延长，目标是在保持可接受的风险水平的同时实现回报最大化。本文提出了一种基于系统风险矩阵的方法，利用现有的设计和状态数据、基于资产特定或分组方法的重新评估结果以及现有的检查结果和策略，对海上设施的剩余寿命进行预测性评估。对每个参数的影响进行加权，根据不同的资产类别进行调整，以获取每个学科或系统中最先进的方法，用于预测剩余寿命。该方法能够处理稀疏数据并合并最近或计划的修改。随着时间的推移，由于损坏或退化而增加的故障可能性，以及其他威胁，如过时，通过与时间相关的因素来捕获，以提供对剩余寿命的估计。该方法根据作业者现有的风险承受能力和管理策略，从一个子系统到整个油田，对资产的健康和剩余寿命进行了灵活的评估。这为作业者提供了一个有价值的工具，帮助优化油田的生命周期成本。如果整体风险概况不可接受，那么可以执行高水平的假设分析，并将其合并到风险模型中，以审查随着设施老化减少可能性或后果的措施。这可能包括额外的评估(例如，平台特定的极限强度或主要设备的适合服务评估)，织物维护或基于风险的检查计划的变更，负载减少，仪器和控制系统的升级，加强，修改或维修计划的实施，或退役。Advisian已经成功地将这种方法应用于海上和陆上资产。与大多数通常局限于单一学科的寿命延长项目不同，该方法提供了一种灵活的多学科方法，能够将包括上层结构、管道、管道、旋转和静态设备、电气和仪表在内的研究结果纳入整个现场评估。
{"title":"Asset Life Extension Management of Aging Offshore Fields","authors":"Joshua Altmann, A. Sherif, R. Nicolson","doi":"10.4043/31640-ms","DOIUrl":"https://doi.org/10.4043/31640-ms","url":null,"abstract":"\u0000 With many of the offshore platforms around the globe well past their design life, developing targeted and cost-effective approaches to reassess and manage the life extension of these facilities is critical for operators. Although standards such as API RP 2SIM and ISO 19901-9 provide an excellent framework for management of the structural integrity of individual platforms, operators that manage a significant number of facilities need to develop strategies for overseeing the life extension of a fleet of aging multidiscipline assets, with the objective of maximizing return while maintaining an acceptable level of risk.\u0000 The paper presents a systematic risk matrix based approach to provide a predictive assessment of the residual lives of the offshore facilities using the available design and condition data, re-assessment results based on asset specific or grouped approaches, and existing inspection results and strategies. Weighting of the influence of each parameter, adapted for different asset classes to capture state-of-the-art approaches within each discipline or system, is used to predicted residual life. This method has the ability to handle sparse data and incorporate recent or planned modifications. The increased likelihood of failure with time due to damage or degradation, as well as other threats such as obsolesce, is captured through time dependent factors to provide an estimate of the residual life.\u0000 The method used provides a flexible assessment of the health and residual life estimates for assets from a sub-system through to a full field perspective based on the existing risk tolerance and management strategies of the operator. This provides operators with a valuable tool to assist in optimizing the life cycle costs for the field. If the overall risk profile is not acceptable, then high level what-if analyses can be performed and incorporated into the risk model to review likelihood or consequence reducing measures as the facilities age. This may include additional assessments (e.g. platform specific ultimate strength or fitness-for-service assessments of major equipment), changes to fabric maintenance or risk based inspection plans, load reductions, upgrading of instrumentation and control systems, implementation of strengthening, modification or repair programs, or decommissioning. Advisian has successfully applied this approach for both offshore and onshore assets.\u0000 Unlike most life extension programs which are typically limited to a single discipline, this method provides a flexible multidisciplinary approach with the ability to incorporate findings covering topside structures, pipelines, piping, rotating and static equipment, electrical and instrumentation for a whole of field assessment.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"114 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79888100","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 recent trends indicate strong growth opportunities in the FPSO market. Securing financing for projects, however, will continue to be a challenge – given the rising expectations of the investment market. This paper presents a methodology to address demand for climate-related information by investors. It provides practical guidance to build a robust framework – to boost environmental credentials, enhance investor and lender confidence and improve access to capital.
{"title":"The Journey Towards a Net-Zero Emission Future","authors":"S. Venkatesh","doi":"10.4043/31364-ms","DOIUrl":"https://doi.org/10.4043/31364-ms","url":null,"abstract":"\u0000 The recent trends indicate strong growth opportunities in the FPSO market. Securing financing for projects, however, will continue to be a challenge – given the rising expectations of the investment market.\u0000 This paper presents a methodology to address demand for climate-related information by investors. It provides practical guidance to build a robust framework – to boost environmental credentials, enhance investor and lender confidence and improve access to capital.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"41 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91329468","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}
P. Chidambaram, P. A. Patil, P. Tiwari, D. Das, R. Tewari
Storing CO2 in geological formations is gaining greater importance as various companies start transitioning towards a carbon neutral future. CO2 storage in depleted hydrocarbon reservoirs and saline aquifers is considered an effective and secure option to reduce atmospheric CO2. Once underground, four different mechanisms keep the supercritical CO2 securely stored. The mechanisms, in increasing order of storage security are, 1. Structural/stratigraphic trapping, 2. Residual trapping, 3. Solubility trapping, and 4. Mineral trapping. Optimization of injector design to increase the amount of CO2 trapped in one of the more secure mechanisms is desirable. Structural trapping is the most dominant and least secure trapping mechanism for CO2 storage. Any opportunity to move structurally trapped CO2 into one of the other trapping mechanisms is preferable from the standpoint of storage security. Mechanistic models are used to study ways to improve amount of CO2 trapped by certain mechanisms. Residual trapping is affected by several factors including path traveled from perforation to the top of the structure. Similarly, solubility trapping is influenced by several factors including the amount of contact CO2 has with water. Injected CO2, due to buoyancy, rapidly rises to the top of the structure. There is potential to increase residual trapping and solubility trapping by optimizing the injector design to increase volume of reservoir contacted by CO2. Mechanistic modeling study shows that residual trapped and solubility trapped CO2 volume can be increased by optimizing injector design. There is up to 50% improvement observed in both trapping mechanisms depending on the reservoir characteristics and injector design. Interestingly, lower permeability reservoirs are more sensitive to injector design compared to higher permeability reservoirs. Of the injector designs studied, horizontal injectors placed at the bottom of the structure show the most improvement in both residual and solubility trapping mechanisms. Pressure of the reservoir also influences trapping mechanisms. At higher reservoir pressures, density difference between CO2 and water is smaller. This affects how CO2 plume migrates in the reservoir.
{"title":"Injector Design Plays an Important Role In Maximisation of CO2 Trapping in Geological Formations","authors":"P. Chidambaram, P. A. Patil, P. Tiwari, D. Das, R. Tewari","doi":"10.4043/31425-ms","DOIUrl":"https://doi.org/10.4043/31425-ms","url":null,"abstract":"\u0000 Storing CO2 in geological formations is gaining greater importance as various companies start transitioning towards a carbon neutral future. CO2 storage in depleted hydrocarbon reservoirs and saline aquifers is considered an effective and secure option to reduce atmospheric CO2. Once underground, four different mechanisms keep the supercritical CO2 securely stored. The mechanisms, in increasing order of storage security are, 1. Structural/stratigraphic trapping, 2. Residual trapping, 3. Solubility trapping, and 4. Mineral trapping. Optimization of injector design to increase the amount of CO2 trapped in one of the more secure mechanisms is desirable.\u0000 Structural trapping is the most dominant and least secure trapping mechanism for CO2 storage. Any opportunity to move structurally trapped CO2 into one of the other trapping mechanisms is preferable from the standpoint of storage security. Mechanistic models are used to study ways to improve amount of CO2 trapped by certain mechanisms. Residual trapping is affected by several factors including path traveled from perforation to the top of the structure. Similarly, solubility trapping is influenced by several factors including the amount of contact CO2 has with water. Injected CO2, due to buoyancy, rapidly rises to the top of the structure. There is potential to increase residual trapping and solubility trapping by optimizing the injector design to increase volume of reservoir contacted by CO2.\u0000 Mechanistic modeling study shows that residual trapped and solubility trapped CO2 volume can be increased by optimizing injector design. There is up to 50% improvement observed in both trapping mechanisms depending on the reservoir characteristics and injector design. Interestingly, lower permeability reservoirs are more sensitive to injector design compared to higher permeability reservoirs. Of the injector designs studied, horizontal injectors placed at the bottom of the structure show the most improvement in both residual and solubility trapping mechanisms. Pressure of the reservoir also influences trapping mechanisms. At higher reservoir pressures, density difference between CO2 and water is smaller. This affects how CO2 plume migrates in the reservoir.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"62 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90099264","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}
Deem N Alkuroud, Zeeshan Tariq, A. Khalil, M. Mahmoud, Manar Alahmari, Mohammad Bataweel
Sand production from a poorly consolidated reservoir formation is always considered a challenging problem in the petroleum industry. Sand production can cause erosion and corrosion to downhole and surface equipment and loss of production. Over the past few decades, sand control techniques have attracted increased attention to improve and enhance the characteristics of weak sand formations. Enzyme-induced calcite precipitation (EICP) is considered a relatively new sustainable technique studied for soil improvement. In-situ calcite precipitation in the sand can restrict the movement of the grains by forming bridges. This precipitation fills the pores and binds sand particles causing a reduction in the porosity which as a result improves sand shear strength. In this study, different mixes of EICP solution were studied and tested in the laboratory. To cure the samples at higher temperatures Xanthan Gum (XC-polymer) was used as a temperature stabilizer. EICP solution is primarily composed of urea, calcium chloride, magnesium chloride, XC-polymer, and urease enzyme. Different concentrations and compositions of reagents were tested. The mixed solutions were left for different curing times at different curing temperatures to allow the reaction to happen. The properties of the produced precipitates were examined through different techniques such as pH, conductivity, Fourier-transform infrared spectroscopy (FTIR), X-ray diffraction analysis (XRD), and Thermogravimetric analysis (TGA). The XRD results showed the precipitation of calcite and dolomite. The combination that produced the highest amount of thermally stable calcite with a minimal amount of aragonite, highest precipitation efficiency was further selected for the sand consolidation experiment. A solution containing 1M Urea, 0.5M CaCl2, 0.5M MgCl2, 5g/L XC-polymer, and 2g/L urease was considered as an optimum combination for an EICP process. The novelty of this paper is that it not only describes the development of a unique formula for the EICP process used for sand control and water conformance but also provides a selection criterion for applying the EICP for these downhole applications.
{"title":"Optimization of Enzyme-Induced Calcite Precipitation Process for Oil and Gas Sand Consolidation Applications","authors":"Deem N Alkuroud, Zeeshan Tariq, A. Khalil, M. Mahmoud, Manar Alahmari, Mohammad Bataweel","doi":"10.4043/31454-ms","DOIUrl":"https://doi.org/10.4043/31454-ms","url":null,"abstract":"\u0000 Sand production from a poorly consolidated reservoir formation is always considered a challenging problem in the petroleum industry. Sand production can cause erosion and corrosion to downhole and surface equipment and loss of production. Over the past few decades, sand control techniques have attracted increased attention to improve and enhance the characteristics of weak sand formations. Enzyme-induced calcite precipitation (EICP) is considered a relatively new sustainable technique studied for soil improvement. In-situ calcite precipitation in the sand can restrict the movement of the grains by forming bridges. This precipitation fills the pores and binds sand particles causing a reduction in the porosity which as a result improves sand shear strength.\u0000 In this study, different mixes of EICP solution were studied and tested in the laboratory. To cure the samples at higher temperatures Xanthan Gum (XC-polymer) was used as a temperature stabilizer. EICP solution is primarily composed of urea, calcium chloride, magnesium chloride, XC-polymer, and urease enzyme. Different concentrations and compositions of reagents were tested. The mixed solutions were left for different curing times at different curing temperatures to allow the reaction to happen. The properties of the produced precipitates were examined through different techniques such as pH, conductivity, Fourier-transform infrared spectroscopy (FTIR), X-ray diffraction analysis (XRD), and Thermogravimetric analysis (TGA).\u0000 The XRD results showed the precipitation of calcite and dolomite. The combination that produced the highest amount of thermally stable calcite with a minimal amount of aragonite, highest precipitation efficiency was further selected for the sand consolidation experiment. A solution containing 1M Urea, 0.5M CaCl2, 0.5M MgCl2, 5g/L XC-polymer, and 2g/L urease was considered as an optimum combination for an EICP process.\u0000 The novelty of this paper is that it not only describes the development of a unique formula for the EICP process used for sand control and water conformance but also provides a selection criterion for applying the EICP for these downhole applications.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84852027","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}
It is well known that formations can be very abrasive, and can quickly and severely wear drill pipe tube bodies. Once the body wall of the tube no longer meets requirements for used pipe, the entire joint must be scrapped. A new method of applying sacrificial wear pads to drill pipe tube bodies is presented, by using a proprietary low heat input welding process to apply hardbanding directly to drill pipe tubes. Using a proprietary low heat input welding process, hardbanding was safely applied to drill pipe tube bodies. This created new, raised contact areas for the tubes with the abrasive formation. Two wear bands consisting of this hardbanding create a wear pad for the tube body, improving its overall wear-resistance by up to 15 times and casing-friendliness up to 3 times. The application itself was validated through metallurgical testing, including advanced hardness mapping, tensile testing, and non-destructive inspection methods. Following this testing, multiple field trials were performed, which provided case studies for the effectiveness of the wear pads. Three separate oil and gas Exploration & Production (E&P) companies were having issues with tube body wear of drill pipe in various formations in the USA. To address this, wear pads were applied to a sample set of drill pipe for each E&P company using a proprietary low heat input welding process. Measurements were taken from the drill pipe before and after drilling activities to determine if the wear pads protected the pipe as planned. In addition, non-destructive testing was performed on the wear pads to determine if any cracks existed. For all three case studies, the wear pads effectively protected the tube bodies of the drill pipe, preventing them from wearing. This proved that the wear pads were a cost-effective solution for protecting pipe from abrasive conditions downhole. The novelty of this improved welding method is that it allows for the economical protection of drill pipe that would otherwise be scrapped due to tube body wear. This extends the life of the drill pipe itself, which is of great value to owners of drill pipe and E&P companies that rent or own strings. Furthermore, the hardbanding used for the wear pad is far more casing-friendly than the unprotected tube, which is also very important to E&P companies.
{"title":"A New Way to Extend the Life of Pipe","authors":"Austin J. Wells","doi":"10.4043/31448-ms","DOIUrl":"https://doi.org/10.4043/31448-ms","url":null,"abstract":"\u0000 It is well known that formations can be very abrasive, and can quickly and severely wear drill pipe tube bodies. Once the body wall of the tube no longer meets requirements for used pipe, the entire joint must be scrapped. A new method of applying sacrificial wear pads to drill pipe tube bodies is presented, by using a proprietary low heat input welding process to apply hardbanding directly to drill pipe tubes.\u0000 Using a proprietary low heat input welding process, hardbanding was safely applied to drill pipe tube bodies. This created new, raised contact areas for the tubes with the abrasive formation. Two wear bands consisting of this hardbanding create a wear pad for the tube body, improving its overall wear-resistance by up to 15 times and casing-friendliness up to 3 times. The application itself was validated through metallurgical testing, including advanced hardness mapping, tensile testing, and non-destructive inspection methods. Following this testing, multiple field trials were performed, which provided case studies for the effectiveness of the wear pads.\u0000 Three separate oil and gas Exploration & Production (E&P) companies were having issues with tube body wear of drill pipe in various formations in the USA. To address this, wear pads were applied to a sample set of drill pipe for each E&P company using a proprietary low heat input welding process. Measurements were taken from the drill pipe before and after drilling activities to determine if the wear pads protected the pipe as planned. In addition, non-destructive testing was performed on the wear pads to determine if any cracks existed. For all three case studies, the wear pads effectively protected the tube bodies of the drill pipe, preventing them from wearing. This proved that the wear pads were a cost-effective solution for protecting pipe from abrasive conditions downhole.\u0000 The novelty of this improved welding method is that it allows for the economical protection of drill pipe that would otherwise be scrapped due to tube body wear. This extends the life of the drill pipe itself, which is of great value to owners of drill pipe and E&P companies that rent or own strings. Furthermore, the hardbanding used for the wear pad is far more casing-friendly than the unprotected tube, which is also very important to E&P companies.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87222897","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 Magnetic Tomography Method (MTM) has been introduced as a non-intrusive inspection technique capable of inspecting ferromagnetic materials such as carbon steel pipeline without any contact. A buried main pipeline in one of PETRONAS's operating countries that had been out of service for more than 8 years needed to be inspected prior to being re-instated. This paper discusses in detail how this innovative MTM technology was used to successfully inspect a decommissioned buried pipeline and safely re-instated the pipeline operation. The MTM inspection covered 172 kilometres of buried pipeline, including the calibration work which involved direct assessment methods. The danger degrees such as Rank 1, 2 and 3, as well as the safe operating pressures, Psafe along the entire pipeline were determined using the MTM results of Risk Factor F in accordance with MTM technical approach. Direct assessment findings were consistent with the MTM inspection findings, as the technology detected all of the anomalies discovered by the direct assessment methods. MTM inspections of decommissioned buried pipelines are proven since they are reliant on the residual self-magnetic leakage field (SMLF) in the pipeline and do not require any intrusive works. Being a non-intrusive inspection method, this technology was not affected by the low pressure & low flowrate, and no changes to the pipeline operation mode was required during the inspection. Further, this MTM inspection method was not affected by the stalled pigs inside the pipeline, as this inspection method was non-intrusive. The inspection results serve as major input to the Pipeline Integrity Management System (PIMS) to effectively manage the integrity and risk level of the pipeline.
{"title":"Non-Contact Magnetic Tomography Method MTM Inspection for Re-Instatement of a Decommissioned Buried Pipeline","authors":"Choong Meng Lam, N.A.H. Jasni","doi":"10.4043/31418-ms","DOIUrl":"https://doi.org/10.4043/31418-ms","url":null,"abstract":"\u0000 The Magnetic Tomography Method (MTM) has been introduced as a non-intrusive inspection technique capable of inspecting ferromagnetic materials such as carbon steel pipeline without any contact. A buried main pipeline in one of PETRONAS's operating countries that had been out of service for more than 8 years needed to be inspected prior to being re-instated. This paper discusses in detail how this innovative MTM technology was used to successfully inspect a decommissioned buried pipeline and safely re-instated the pipeline operation. The MTM inspection covered 172 kilometres of buried pipeline, including the calibration work which involved direct assessment methods. The danger degrees such as Rank 1, 2 and 3, as well as the safe operating pressures, Psafe along the entire pipeline were determined using the MTM results of Risk Factor F in accordance with MTM technical approach. Direct assessment findings were consistent with the MTM inspection findings, as the technology detected all of the anomalies discovered by the direct assessment methods. MTM inspections of decommissioned buried pipelines are proven since they are reliant on the residual self-magnetic leakage field (SMLF) in the pipeline and do not require any intrusive works. Being a non-intrusive inspection method, this technology was not affected by the low pressure & low flowrate, and no changes to the pipeline operation mode was required during the inspection. Further, this MTM inspection method was not affected by the stalled pigs inside the pipeline, as this inspection method was non-intrusive. The inspection results serve as major input to the Pipeline Integrity Management System (PIMS) to effectively manage the integrity and risk level of the pipeline.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78668015","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 comprehensive series of experiments on foaming of two (2) types of crude oil and four (4) types of synthesized Gemini silicone- amine base defoamer in simulated produced water system containing foam surfactant Foam Assisted-Water Alternating Gas (FAWAG) package were investigated under the influence of column temperature at 30 – 60 °C, applied pressure of 1 – 4 bar, and fixed fluid flowrate of 0.5 L/min. In this study, the presence of high saturates composition in the crude oil which at 45 – 75.8 % influence the foam stability of the fluids. This reflects the waxy types of crude oils with higher density properties of 0.8768 – 0.858 Kg/L and increase concentration of foam surfactant from 30% to 90% in the produced water system influences the foaming stability. The microscopic observation shows that bigger bubble size about the average of 400 – 500 µm would slows down the liquid drainage, resulting in foam stability behavior. Defoamers with various structures ranged from amine short-chain, amine long-chain, amine branched-chain and amide-chain were analysed to determine the effect of molecular structure at various concentration from 5 – 40ppm. The defoaming ability was determined by foam height and collapse time. The amide short-chain and amine branched –chain had excellent foam breaking performance which was observed from the mean bubble size reduction to 50 – 100 µm resulting from formation of unstable bridge across lamellae causing the foam to rupture, allowing faster liquid drainage, thus improving suppression performance.
{"title":"Case Study of Managing Surplus Surfactant-Foam Generated from Foam Assisted-Water Alternating Gas","authors":"N. Borhan, Shazleen Saadon, Almila Hassan","doi":"10.4043/31516-ms","DOIUrl":"https://doi.org/10.4043/31516-ms","url":null,"abstract":"\u0000 A comprehensive series of experiments on foaming of two (2) types of crude oil and four (4) types of synthesized Gemini silicone- amine base defoamer in simulated produced water system containing foam surfactant Foam Assisted-Water Alternating Gas (FAWAG) package were investigated under the influence of column temperature at 30 – 60 °C, applied pressure of 1 – 4 bar, and fixed fluid flowrate of 0.5 L/min. In this study, the presence of high saturates composition in the crude oil which at 45 – 75.8 % influence the foam stability of the fluids. This reflects the waxy types of crude oils with higher density properties of 0.8768 – 0.858 Kg/L and increase concentration of foam surfactant from 30% to 90% in the produced water system influences the foaming stability. The microscopic observation shows that bigger bubble size about the average of 400 – 500 µm would slows down the liquid drainage, resulting in foam stability behavior. Defoamers with various structures ranged from amine short-chain, amine long-chain, amine branched-chain and amide-chain were analysed to determine the effect of molecular structure at various concentration from 5 – 40ppm. The defoaming ability was determined by foam height and collapse time. The amide short-chain and amine branched –chain had excellent foam breaking performance which was observed from the mean bubble size reduction to 50 – 100 µm resulting from formation of unstable bridge across lamellae causing the foam to rupture, allowing faster liquid drainage, thus improving suppression performance.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81764708","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}
Jamari M Shah, Nur Athirah Md Dahlan, Hazreen Harris Lee, Nur Fatihah M Zulkifli
Carbonates reservoir has an elevated level of heterogeneity than clastic reservoir, which is relatively controlled only by depositional facies. It is because of the facies variation vertically and laterally which is more intensive, as well as intensive diagenesis. Therefore, an accurate method is required to ensure hydrocarbon development is effective and efficient. Challenges in the characterization of the carbonate are related to rock type and porosity. The permeability of rocks cannot to determined only by porosity. The method that can be used to determine rock type and rock permeability estimation is through rock typing method. This method is aptly applied for carbonate reservoir which is dynamically change due to diagenesis. It is believed to predict and optimize carbonate reservoir better. Core data can be used to determine rock type based on geology named litho-facies or petrophysics named electro-facies characterization There are many rock typing methods, which are Pore throat group based on shape and trend, PGS - Pore geometry structure, Lucia, FZI – flow zone indicator, Winland R35. Those methods use different principles in classifying rock type. Main objective to merge core results between geological statement information based with digital engineering data. By combining these two pieces of information and data, the more precise rock type and able to achieve in solving more finer on carbonate reservoir characterization. Furthermore, the analysis has been conducted over multiple carbonates environments including platform carbonate, pinnacle carbonate and complex carbonate lithology. This paper presents the rock typing classification in carbonate environments which consider geological, and engineering elements mainly through Pore Throat based Rock typing. The main rock typing group can be derived from either stratigraphy or the distribution shape of the pore throat. This will produce the porosity-permeability relationship for all the samples. Geological inputs are then used to describe more refined and detailed characteristics of the relationship. These variety sets of data will help to populate the geological features of the reservoir in bulk and each individual layer in depths. The process includes developing the correlation between pore throat size and pore throat connectivity networking. Defined from core plug pore throat pattern and tie to well logs respond. Consequently, to be propagated in the non-cored intervals through correlation between multiple well logs respond. Some of the key petrophysical measurements will be discussed and how to interpret the borehole images associated with carbonates. As well as looking at different methods of rock typing and best practices to build a static carbonate model. This approach is using pore throat group to classify the rock typing of the carbonate reservoirs. The main rock typing group can be derived from either stratigraphy or the distribution shape of the pore throat. The methodolog
{"title":"Establishing Rapport Throughout Carbonate Reservoirs: A Rock Typing Networking Based on Pore Throat","authors":"Jamari M Shah, Nur Athirah Md Dahlan, Hazreen Harris Lee, Nur Fatihah M Zulkifli","doi":"10.4043/31629-ms","DOIUrl":"https://doi.org/10.4043/31629-ms","url":null,"abstract":"\u0000 Carbonates reservoir has an elevated level of heterogeneity than clastic reservoir, which is relatively controlled only by depositional facies. It is because of the facies variation vertically and laterally which is more intensive, as well as intensive diagenesis. Therefore, an accurate method is required to ensure hydrocarbon development is effective and efficient.\u0000 Challenges in the characterization of the carbonate are related to rock type and porosity. The permeability of rocks cannot to determined only by porosity. The method that can be used to determine rock type and rock permeability estimation is through rock typing method. This method is aptly applied for carbonate reservoir which is dynamically change due to diagenesis. It is believed to predict and optimize carbonate reservoir better. Core data can be used to determine rock type based on geology named litho-facies or petrophysics named electro-facies characterization\u0000 There are many rock typing methods, which are Pore throat group based on shape and trend, PGS - Pore geometry structure, Lucia, FZI – flow zone indicator, Winland R35. Those methods use different principles in classifying rock type. Main objective to merge core results between geological statement information based with digital engineering data. By combining these two pieces of information and data, the more precise rock type and able to achieve in solving more finer on carbonate reservoir characterization. Furthermore, the analysis has been conducted over multiple carbonates environments including platform carbonate, pinnacle carbonate and complex carbonate lithology.\u0000 This paper presents the rock typing classification in carbonate environments which consider geological, and engineering elements mainly through Pore Throat based Rock typing. The main rock typing group can be derived from either stratigraphy or the distribution shape of the pore throat. This will produce the porosity-permeability relationship for all the samples. Geological inputs are then used to describe more refined and detailed characteristics of the relationship. These variety sets of data will help to populate the geological features of the reservoir in bulk and each individual layer in depths.\u0000 The process includes developing the correlation between pore throat size and pore throat connectivity networking. Defined from core plug pore throat pattern and tie to well logs respond. Consequently, to be propagated in the non-cored intervals through correlation between multiple well logs respond. Some of the key petrophysical measurements will be discussed and how to interpret the borehole images associated with carbonates. As well as looking at different methods of rock typing and best practices to build a static carbonate model.\u0000 This approach is using pore throat group to classify the rock typing of the carbonate reservoirs. The main rock typing group can be derived from either stratigraphy or the distribution shape of the pore throat. The methodolog","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91105786","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 conventional dual-porosity model (Warren and Root 1963) may not apply to naturally fractured reservoirs which have poorly connected fractures. To narrow this gap, a discrete fracture model based numerical well testing (NWT) model is developed for pressure transient analysis in vertical wells interacting with natural fractures. The accuracy and practicality of the proposed model have been demonstrated by model verifications. The results show that the flow regimes of the vertical well interacting with natural fractures can be divided into wellbore storage and skin effects, bilinear flow, linear flow, radial flow, natural-fracture (NF) effect, and boundary-dominated flow. This radial flow is the radial flow of the formation before pressure propagates to natural fractures, which is virtually quite different from that in the conventional dual-porosity model (Warren and Root 1963). However, there are no bilinear and linear flow stages in the vertical well interacting with no natural fractures. It is found that the vertical well interacting with natural fractures has a lower pressure depletion. It is also found that the "V-shape" caused by the NF effect in the pressure derivative curve becomes deeper when there are more natural fractures, longer natural fractures, and higher fracture conductivity. Furthermore, the "V-shape" appears earlier and the duration of the NF effect is longer as the number of natural fractures increases. Besides, with the decrease of the distance between the fracture and well, the impacts of natural fractures on pressure transient behaviors of the vertical well are more significant. This work provides a meaningful way to understand the pressure transient behaviors of discrete natural fractures.
传统的双重孔隙度模型(Warren and Root 1963)可能不适用于裂缝连接不良的天然裂缝性储层。为了缩小这一差距，开发了一种基于离散裂缝模型的数值试井(NWT)模型，用于与天然裂缝相互作用的直井压力瞬态分析。通过模型验证，证明了该模型的准确性和实用性。结果表明:直井与天然裂缝相互作用的流动形态可分为井筒储层效应、双线性流、线性流、径向流、天然裂缝效应和边界主导流;这种径向流动是压力传播到天然裂缝之前地层的径向流动，实际上与传统的双重孔隙度模型(Warren and Root 1963)有很大不同。然而，直井中没有双线性和线性流动阶段，没有天然裂缝相互作用。研究发现，与天然裂缝相互作用的直井具有较低的压力衰竭。同时发现，当天然裂缝越多、天然裂缝越长、裂缝导流能力越高时，由NF效应引起的压力导数曲线“v”形越深。随着天然裂缝数量的增加，“v”型裂缝出现的时间越早，NF效应持续的时间越长。此外，随着裂缝与井的距离减小，天然裂缝对直井压力瞬态特性的影响更为显著。这项工作为了解离散天然裂缝的压力瞬态特性提供了一种有意义的方法。
{"title":"Pressure Transient Behaviors of Discretely Fractured Reservoirs Using a Numerical Discrete Fracture Model","authors":"Zhiming Chen, Biao Zhou, Shaoqi Zhang, Wei Yu","doi":"10.4043/31409-ms","DOIUrl":"https://doi.org/10.4043/31409-ms","url":null,"abstract":"\u0000 The conventional dual-porosity model (Warren and Root 1963) may not apply to naturally fractured reservoirs which have poorly connected fractures. To narrow this gap, a discrete fracture model based numerical well testing (NWT) model is developed for pressure transient analysis in vertical wells interacting with natural fractures.\u0000 The accuracy and practicality of the proposed model have been demonstrated by model verifications. The results show that the flow regimes of the vertical well interacting with natural fractures can be divided into wellbore storage and skin effects, bilinear flow, linear flow, radial flow, natural-fracture (NF) effect, and boundary-dominated flow. This radial flow is the radial flow of the formation before pressure propagates to natural fractures, which is virtually quite different from that in the conventional dual-porosity model (Warren and Root 1963). However, there are no bilinear and linear flow stages in the vertical well interacting with no natural fractures. It is found that the vertical well interacting with natural fractures has a lower pressure depletion. It is also found that the \"V-shape\" caused by the NF effect in the pressure derivative curve becomes deeper when there are more natural fractures, longer natural fractures, and higher fracture conductivity. Furthermore, the \"V-shape\" appears earlier and the duration of the NF effect is longer as the number of natural fractures increases. Besides, with the decrease of the distance between the fracture and well, the impacts of natural fractures on pressure transient behaviors of the vertical well are more significant. This work provides a meaningful way to understand the pressure transient behaviors of discrete natural fractures.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75897815","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}
Thin Zar Soe, Anucha Leelaratsameephanit, W. Chantarataneewat, C. Peerakham, Phanuwat Jitputti, T. Kiatrabile
PTTEP's Myanmar Asset Zawtika offshore field is located in the Gulf of Moattama, offshore Myanmar, referred to as the Zawtika Gas Development and Production Area. The area lies approximately 300 km south of Yangon and 290 km west of Tavoy on the Myanmar coast. Zawtika offshore gas field consists of Zawtika Processing and Living Quarter platform (ZPQ) which was designed to provide fully automatic, integrated and centralized platform/ process control, and ZWP1 which is connected to ZPQ via interconnecting bridge and 10 remote wellhead platforms which are ZWP2, ZWP3, ZWP4, ZWP5, ZWP6, ZWP7, ZWP8, ZWP9, ZWP10 and ZWP11, located in the Gulf of Moattama offshore Myanmar. In order to prolong field gas potential, the data analysis, planning and management on daily gas potential loss is important to better understand the field behavior. The issues of gas losses are captured and categorized based on difficulties of recovery. "Deferment" is defined as the short-term temporary reduction in Production Availability which results in delay of gas production due to the effects of system constraints/ limitations, scheduled shut down activities on wells or facilities associated with safety, production, maintenance, operation and unplanned interruptions. "Lock-in" is defined as the long-term gas potential reduction that requires longer time and higher investment to solve and unlock that potential. Under PTTEP Operation Excellent Management System (OEMS), one of the essential elements for optimized operation is deferment/lock-in potential management. With this importance in focus, this paper discusses Deferment Management Enhancement for PTTEP's Myanmar asset operation which goal is to enhance deferment analysis and management by using data analytics in information technology environment in alignment with PTTEP Digital Transformation direction. The data obtained from this enhancement can be used in short-term and long-term planning activities for production system optimization including project investments, reservoir management and integrated operations planning, and especially in providing in-depth analysis to minimize deferment volume to maximize return on investment. Production deferment/lock-in guideline is developed within PTTEP's Myanmar Asset to structure Hydrocarbon Availability Model (HAM) for Zawtika according to PTTEP Operations Standard and define deferment and lock-in gas potential data collection basis and their categorizations. ZPDMS deferment module is then enhanced based on this guideline with the extra capability to facilitate site data entry which has been a problem since start-up due to satellite link constraint from Zawtika offshore field. This enhancement also consolidates lock-in/deferment causes, and coding structures, integrates subsurface potential calculation and surface production data, and introduces key visualization pages (e.g. Deferment Dashboard, etc.) for better deferment management performance analysis. After the full implemen
{"title":"Zawtika Deferment Management Enhancement: A Systematic Way to Unlock Gas Potential for Optimized Operations","authors":"Thin Zar Soe, Anucha Leelaratsameephanit, W. Chantarataneewat, C. Peerakham, Phanuwat Jitputti, T. Kiatrabile","doi":"10.4043/31572-ms","DOIUrl":"https://doi.org/10.4043/31572-ms","url":null,"abstract":"\u0000 PTTEP's Myanmar Asset Zawtika offshore field is located in the Gulf of Moattama, offshore Myanmar, referred to as the Zawtika Gas Development and Production Area. The area lies approximately 300 km south of Yangon and 290 km west of Tavoy on the Myanmar coast. Zawtika offshore gas field consists of Zawtika Processing and Living Quarter platform (ZPQ) which was designed to provide fully automatic, integrated and centralized platform/ process control, and ZWP1 which is connected to ZPQ via interconnecting bridge and 10 remote wellhead platforms which are ZWP2, ZWP3, ZWP4, ZWP5, ZWP6, ZWP7, ZWP8, ZWP9, ZWP10 and ZWP11, located in the Gulf of Moattama offshore Myanmar.\u0000 In order to prolong field gas potential, the data analysis, planning and management on daily gas potential loss is important to better understand the field behavior. The issues of gas losses are captured and categorized based on difficulties of recovery. \"Deferment\" is defined as the short-term temporary reduction in Production Availability which results in delay of gas production due to the effects of system constraints/ limitations, scheduled shut down activities on wells or facilities associated with safety, production, maintenance, operation and unplanned interruptions. \"Lock-in\" is defined as the long-term gas potential reduction that requires longer time and higher investment to solve and unlock that potential.\u0000 Under PTTEP Operation Excellent Management System (OEMS), one of the essential elements for optimized operation is deferment/lock-in potential management. With this importance in focus, this paper discusses Deferment Management Enhancement for PTTEP's Myanmar asset operation which goal is to enhance deferment analysis and management by using data analytics in information technology environment in alignment with PTTEP Digital Transformation direction. The data obtained from this enhancement can be used in short-term and long-term planning activities for production system optimization including project investments, reservoir management and integrated operations planning, and especially in providing in-depth analysis to minimize deferment volume to maximize return on investment.\u0000 Production deferment/lock-in guideline is developed within PTTEP's Myanmar Asset to structure Hydrocarbon Availability Model (HAM) for Zawtika according to PTTEP Operations Standard and define deferment and lock-in gas potential data collection basis and their categorizations. ZPDMS deferment module is then enhanced based on this guideline with the extra capability to facilitate site data entry which has been a problem since start-up due to satellite link constraint from Zawtika offshore field. This enhancement also consolidates lock-in/deferment causes, and coding structures, integrates subsurface potential calculation and surface production data, and introduces key visualization pages (e.g. Deferment Dashboard, etc.) for better deferment management performance analysis.\u0000 After the full implemen","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74068615","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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