Suction embedded plate anchors (SEPLAs) are an economic solution for the mooring system of a floating production platform and have been deployed both in the Gulf of Mexico (GoM) and around the globe with excellent field performance records. The design of SEPLAs has gradually matured over the past two decades for conventional SEPLAs, but debates continue both in the industry and academia, e.g., on the function of the flap and the required keying. These design aspects become more critical for permanent mooring systems in the GoM where the anchors have to resist large mooring tensions from hurricanes, and balancing safety and economy is a challenge. Thus, the objective of this paper is to present design considerations for large-size SEPLAs for permanent mooring systems in the GoM. The design considerations in this paper include the embedment loss, the functions of the flap and keying, cyclic loading, sustained loading, keying disturbance, and out-of-plane loading. Recommendations are provided to advance the design of large-size SEPLAs, and more specific guidance is offered relative to the ambiguous requirements currently in the industry guidelines.
{"title":"Design of Large-Size Suction Embedded Plate Anchors for Permanent Mooring Systems in the Gulf of Mexico","authors":"Jinbo Chen, C. Heyl, J. Newlin, M. Karayaka","doi":"10.4043/31129-ms","DOIUrl":"https://doi.org/10.4043/31129-ms","url":null,"abstract":"\u0000 Suction embedded plate anchors (SEPLAs) are an economic solution for the mooring system of a floating production platform and have been deployed both in the Gulf of Mexico (GoM) and around the globe with excellent field performance records. The design of SEPLAs has gradually matured over the past two decades for conventional SEPLAs, but debates continue both in the industry and academia, e.g., on the function of the flap and the required keying. These design aspects become more critical for permanent mooring systems in the GoM where the anchors have to resist large mooring tensions from hurricanes, and balancing safety and economy is a challenge. Thus, the objective of this paper is to present design considerations for large-size SEPLAs for permanent mooring systems in the GoM. The design considerations in this paper include the embedment loss, the functions of the flap and keying, cyclic loading, sustained loading, keying disturbance, and out-of-plane loading. Recommendations are provided to advance the design of large-size SEPLAs, and more specific guidance is offered relative to the ambiguous requirements currently in the industry guidelines.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73966418","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 new edition of the ISO 15663 standard has been developed during the recent years and will strengthen the industry cost management for business value creation. This paper shows how such standardization can be used to further enhance and promote adoption of a common and consistent approach to life cycle costing in the offshore oil and gas industry. The new ISO 15663 edition maintains key principles from previous editions, but does also introduce an improved and revised management methodology for application of life cycle costing. The purpose is to provide decision support for selecting between alternative options (e.g., projects, operational and technical subject matters) across life cycle phases, also aligned with overall corporate business objectives such as HSE and sustainability. It also provides the means of identifying cost drivers and a framework for value optimization over the entire life of an asset. The international standard is providing an essential set of normative requirements on how to implement and apply the life cycle costing methodology and the decision criteria, supported by an exhaustive part of recommended practices. This includes the identification of common and specific contractual considerations for operators, contractors and vendors (e.g., complementary metrics besides expenditure, such as systems availability guarantee and risk-sharing clauses). It also includes the application in the life cycle phases of an asset, the techniques and data input, examples of application, and assessment and lessons learnt. Capital expenditure (CAPEX), operating expenditure (OPEX), revenue and lost revenue (LOSTREV) factors are addressed. The standard includes an unambiguous definition of the economic objectives of a project and application of the same business criteria when making major engineering decisions. The life cycle costing methodology is applicable to all asset decisions in any life cycle phase, but should be applied only when expected to add value for decision-support. The required extent of planning and management of the appropriate life cycle costing is depending on the magnitude of the costs involved, the potential value that can be created and the life cycle phase. This paper demonstrates how the new ISO 15663 can be utilized by providing new examples of life cycle costing, to give all participants in the process — oil and gas operators, contractors and vendors — an up-to-date and streamlined set of requirements and guidance, encouraging a fit for purpose application. The paper does also present unique key economic evaluation measures such as life cycle cost (LCC) and net present value (NPV).
{"title":"Value Creation and Cost Management by Use of the New ISO 15663 Life Cycle Costing Standard","authors":"Endre Willmann, R. Østebø, E. Montalvão","doi":"10.4043/31203-ms","DOIUrl":"https://doi.org/10.4043/31203-ms","url":null,"abstract":"\u0000 The new edition of the ISO 15663 standard has been developed during the recent years and will strengthen the industry cost management for business value creation. This paper shows how such standardization can be used to further enhance and promote adoption of a common and consistent approach to life cycle costing in the offshore oil and gas industry.\u0000 The new ISO 15663 edition maintains key principles from previous editions, but does also introduce an improved and revised management methodology for application of life cycle costing. The purpose is to provide decision support for selecting between alternative options (e.g., projects, operational and technical subject matters) across life cycle phases, also aligned with overall corporate business objectives such as HSE and sustainability. It also provides the means of identifying cost drivers and a framework for value optimization over the entire life of an asset.\u0000 The international standard is providing an essential set of normative requirements on how to implement and apply the life cycle costing methodology and the decision criteria, supported by an exhaustive part of recommended practices. This includes the identification of common and specific contractual considerations for operators, contractors and vendors (e.g., complementary metrics besides expenditure, such as systems availability guarantee and risk-sharing clauses). It also includes the application in the life cycle phases of an asset, the techniques and data input, examples of application, and assessment and lessons learnt. Capital expenditure (CAPEX), operating expenditure (OPEX), revenue and lost revenue (LOSTREV) factors are addressed. The standard includes an unambiguous definition of the economic objectives of a project and application of the same business criteria when making major engineering decisions. The life cycle costing methodology is applicable to all asset decisions in any life cycle phase, but should be applied only when expected to add value for decision-support. The required extent of planning and management of the appropriate life cycle costing is depending on the magnitude of the costs involved, the potential value that can be created and the life cycle phase.\u0000 This paper demonstrates how the new ISO 15663 can be utilized by providing new examples of life cycle costing, to give all participants in the process — oil and gas operators, contractors and vendors — an up-to-date and streamlined set of requirements and guidance, encouraging a fit for purpose application. The paper does also present unique key economic evaluation measures such as life cycle cost (LCC) and net present value (NPV).","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85688474","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. S. Mohamed, Syafiq Effendi Jalis, Intiran Raman, Kumanan Sanmugam, Dhanaraj Turunawarasu, M. F. Samsudin, Al Ashraf Zharif Al Bakri, Kassim Selamat
Hydrate occurrence is synonymous in deep water wells, notably when the well experience significant reduction in fluid temperature during production. Hence, the operating philosophy must take into consideration the ability to maintain the well-fluid outside the hydrate or wax phase envelope and ensure the contingencies are in place to mitigate any plug, deposit or gel formation. This paper illustrates the characterization of hydrate and wax plug encountered and devise of innovative solution to remediate the blockage in two wells in Sabah waters which were plugged due to cooling of the wells during an unplanned shut down. The solution devised is to set precedence to manage temperature dependent blockages in similar Deepwater wells or facilities. Hydrate and wax models were created to predict blockage severity and its location. Nodal analysis was used to model thermodynamic equilibrium at target location of the plug where the temperature is below the melting point and ultimately to predict the required heat to dissolve the blockages. A Thermo-chemical system was identified, selected, and customized and then injected into well to ensure the temperature generated at the location of the plug was above the melting point of hydrate and wax. Thermo-chemical injection was identified as a viable method of In-situ Heat Generating Technique to generate heat at desired location. The chemical solution was injected via capillary tubing to transmit the heat via conduction and convection to melt the hydrate and paraffinic plug in these 2 wells. An arriving temperature of 40°C at the target zones was required to melt the plug. A positive pressure was maintained in the production tubing during chemical injection to avoid rapid pressure increase as the hydrate plugs dissolved. A temperature of 100 °C was recorded at the wellhead throughout the injection. The downhole gauge indicated positive response, suggesting the heat generated transmitted effectively. After a short duration of injection, communication was established. Hydrate inhibitor was injected to secure the well prior to unloading. The wells were successfully relieved and stabilized production of 1,200 bopd and 800 bopd respectively. The simulation was redesigned based on data collected from the operation to improve the model and to be used for future works. The ability to integrate laboratory analysis, computer aided simulation and operational data was integral to this paper demonstrating an effective way to characterize temperature dependent blockages in production system. Design of experiments provided better insight to address the problem. Innovative use of novel chemistry to produce heat, in-situ heat solved hydrate and wax related issues in a most cost-effective manner. The process of customizing a chemical system based on laboratory and simulation results was effective in ensuring delivery of the results. The bull-heading operation to inject the chemical system proved to be a cost-effective remed
{"title":"Restoring Technical Potential of Deep-Water Well Impaired by Hydrate Plug Embedded with Wax Deposit with Improved Characterization and Innovative Chemistry","authors":"A. S. Mohamed, Syafiq Effendi Jalis, Intiran Raman, Kumanan Sanmugam, Dhanaraj Turunawarasu, M. F. Samsudin, Al Ashraf Zharif Al Bakri, Kassim Selamat","doi":"10.4043/31232-ms","DOIUrl":"https://doi.org/10.4043/31232-ms","url":null,"abstract":"\u0000 Hydrate occurrence is synonymous in deep water wells, notably when the well experience significant reduction in fluid temperature during production. Hence, the operating philosophy must take into consideration the ability to maintain the well-fluid outside the hydrate or wax phase envelope and ensure the contingencies are in place to mitigate any plug, deposit or gel formation. This paper illustrates the characterization of hydrate and wax plug encountered and devise of innovative solution to remediate the blockage in two wells in Sabah waters which were plugged due to cooling of the wells during an unplanned shut down. The solution devised is to set precedence to manage temperature dependent blockages in similar Deepwater wells or facilities.\u0000 Hydrate and wax models were created to predict blockage severity and its location. Nodal analysis was used to model thermodynamic equilibrium at target location of the plug where the temperature is below the melting point and ultimately to predict the required heat to dissolve the blockages. A Thermo-chemical system was identified, selected, and customized and then injected into well to ensure the temperature generated at the location of the plug was above the melting point of hydrate and wax.\u0000 Thermo-chemical injection was identified as a viable method of In-situ Heat Generating Technique to generate heat at desired location. The chemical solution was injected via capillary tubing to transmit the heat via conduction and convection to melt the hydrate and paraffinic plug in these 2 wells. An arriving temperature of 40°C at the target zones was required to melt the plug. A positive pressure was maintained in the production tubing during chemical injection to avoid rapid pressure increase as the hydrate plugs dissolved. A temperature of 100 °C was recorded at the wellhead throughout the injection. The downhole gauge indicated positive response, suggesting the heat generated transmitted effectively. After a short duration of injection, communication was established. Hydrate inhibitor was injected to secure the well prior to unloading. The wells were successfully relieved and stabilized production of 1,200 bopd and 800 bopd respectively. The simulation was redesigned based on data collected from the operation to improve the model and to be used for future works.\u0000 The ability to integrate laboratory analysis, computer aided simulation and operational data was integral to this paper demonstrating an effective way to characterize temperature dependent blockages in production system. Design of experiments provided better insight to address the problem. Innovative use of novel chemistry to produce heat, in-situ heat solved hydrate and wax related issues in a most cost-effective manner. The process of customizing a chemical system based on laboratory and simulation results was effective in ensuring delivery of the results. The bull-heading operation to inject the chemical system proved to be a cost-effective remed","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"147 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86026680","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}
José A. Oliveira, P. Tavares, V. C. Silva, Ivan Noville Rocha Correa Lima, João Francisco Fleck Heck Britto, Thierry Hernalsteens, Marcio Kahn
The purpose of this paper is to present a general overview of the Buzios field development plan, projects’ features, and main achievements so far. The development plan adopted a strategy to pursue the balance between acceleration and cash flow optimization, to maximize the return on the huge investment on the block acquisition, and the risk management related to developing several Greenfield Projects simultaneously. To reduce reservoir uncertainties, a comprehensive data acquisition plan was crafted and implemented considering: (a) seismic acquisition, (b) drilling, logging and testing several exploratory and appraisal wells, (c) massive rock and fluid data sampling along the reservoirs, (d) execution of one Extended Well Test and three Early Production Systems. Additionally, the basic design of wells, subsea systems and Floating Production Storage and Offloading ("FPSO") provided flexibility to cover remaining uncertainties yet present in the Transfer of Rights ("ToR") scope, which allows up to 3,150 billion barrels of oil equivalent ("boe") to be produced. This led to technological challenges that needed to be addressed during project planning. We believe that the innovative solutions applied enhanced currently available technologies and delivered an important legacy to the offshore oil and gas industry. Finally, the results obtained so far, with the ramp-up of Buzios projects 1, 2, 3, and 4 provide evidence of the successful adopted strategy and reinforce the decision of deployment of a fifth FPSO under the scope of the ToR contract. The strong results of the asset led to the acquisition of 90% of the Transfer of Rights Surplus ("ToR+"), together with CNOOC Petroleum Brasil Ltda. (5%) and CNODC Brasil Petróleo e Gás Ltda. (5%), which now paves the way for a second wave of development, including the deployment of up to seven additional FPSOs.
本文的目的是对Buzios油田开发计划、项目特点和迄今为止的主要成果进行概述。该开发计划采取了加速与优化现金流平衡的策略，以最大限度地提高区块收购的巨额投资回报，以及同时开发多个绿地项目的风险管理。为了减少储层的不确定性，制定并实施了一项全面的数据采集计划，考虑了:(a)地震采集，(b)钻井、测井和测试几口勘探和评价井，(c)沿着储层进行大量岩石和流体数据采样，(d)执行一个扩展井测试和三个早期生产系统。此外，油井、海底系统和浮式生产储卸(FPSO)的基本设计提供了灵活性，以应对权利转让(ToR)范围内存在的剩余不确定性，该范围允许生产高达31500亿桶油当量(boe)。这导致了需要在项目规划期间解决的技术挑战。我们相信，创新的解决方案应用了现有技术，并为海上油气行业带来了重要的遗产。最后，到目前为止，随着Buzios项目1、2、3和4的增加，所获得的结果为成功采用的战略提供了证据，并加强了在ToR合同范围内部署第五艘FPSO的决定。该资产的强劲业绩导致与中海油巴西石油有限公司一起收购了90%的转让权剩余(“ToR+”)。(5%)和CNODC Brasil Petróleo e Gás Ltda。(5%)，这为第二波开发铺平了道路，包括部署多达7艘fpso。
{"title":"Buzios: The Largest Ultra-Deepwater Oilfield to Date","authors":"José A. Oliveira, P. Tavares, V. C. Silva, Ivan Noville Rocha Correa Lima, João Francisco Fleck Heck Britto, Thierry Hernalsteens, Marcio Kahn","doi":"10.4043/31154-ms","DOIUrl":"https://doi.org/10.4043/31154-ms","url":null,"abstract":"\u0000 The purpose of this paper is to present a general overview of the Buzios field development plan, projects’ features, and main achievements so far.\u0000 The development plan adopted a strategy to pursue the balance between acceleration and cash flow optimization, to maximize the return on the huge investment on the block acquisition, and the risk management related to developing several Greenfield Projects simultaneously. To reduce reservoir uncertainties, a comprehensive data acquisition plan was crafted and implemented considering: (a) seismic acquisition, (b) drilling, logging and testing several exploratory and appraisal wells, (c) massive rock and fluid data sampling along the reservoirs, (d) execution of one Extended Well Test and three Early Production Systems.\u0000 Additionally, the basic design of wells, subsea systems and Floating Production Storage and Offloading (\"FPSO\") provided flexibility to cover remaining uncertainties yet present in the Transfer of Rights (\"ToR\") scope, which allows up to 3,150 billion barrels of oil equivalent (\"boe\") to be produced. This led to technological challenges that needed to be addressed during project planning. We believe that the innovative solutions applied enhanced currently available technologies and delivered an important legacy to the offshore oil and gas industry.\u0000 Finally, the results obtained so far, with the ramp-up of Buzios projects 1, 2, 3, and 4 provide evidence of the successful adopted strategy and reinforce the decision of deployment of a fifth FPSO under the scope of the ToR contract. The strong results of the asset led to the acquisition of 90% of the Transfer of Rights Surplus (\"ToR+\"), together with CNOOC Petroleum Brasil Ltda. (5%) and CNODC Brasil Petróleo e Gás Ltda. (5%), which now paves the way for a second wave of development, including the deployment of up to seven additional FPSOs.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"352 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84875572","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}
Raj Kumar, S. Mukherjee, S. K. Biswal, R. V, S. Subbiah, J. Zacharia, R. Talreja, A. Bandyopadhyay, M. Singh
Hydrocarbon exploration continues to venture into new avenues. This paper elaborates the 3D geomechanical study carried out to identify sweet spots in Deccan Trap Basalts in depth ranging from 500m-1100m in Cambay basin field of India. The main challenge is wide variation in the rock mechanical properties and stress profiles along various azimuths resulting from different tectonic incidents over the geological ages. Several drilling complications and held ups during electro logging in highly deviated wells are also reported. The normal fault tectonic framework has the imprint of two sets of faults viz., NNW-SSE and ENE-WSW. Deccan Trap acts as reservoirs due to the presence of connected open fracture network and to assess the potential reserves a comprehensive 3D Critically stressed fracture analysis has been performed using 3D numerical simulation-based rock properties, in-situ stress and seismic data. Open hole geophysical logs like sonic dipole and borehole images have been used to estimate rock mechanical properties and stress profiles in 18 key wells. Available core data of Basalt in the area have been used for dynamic to static rock properties estimation along with available published literature data. Critically stressed fracture analysis using 1D MEM outputs and dips dataset has been performed at well scale to history match production logging and testing results of 23 wells located in different fault blocks. 3D stress model has been built using plasticity model while taking into account faults and fracture sets. Utilizing 3D Geomechanical properties and Discrete fracture network model, critically stressed fracture sets have been identified across the field with slip tolerance and effective drawdown pressures. The study suggests that structurally high locations are good producers if seals are present above Trap. Sub-horizontal fractures have a higher closing tendency with decline in pressure in layers with SHmax>SHmin>Sv inside stiff Trap layer. There is variation of slip tolerance in the range of 0.2-1.4 in fracture sets which indicates slip tendency to be varying both vertically and laterally. Faults with ENE-WSW strike seem to be fluid migratory conduits and their intersection with NNW-SSE discontinuities are the areas where fracture sets have a higher slip tendency. Most of the producing layers are within 25m-55m of Trap with water being encountered at deeper depth intervals. These are mostly weathered fractured layers within the trap. The stress map suggests rotation of the maximum horizontal stress azimuth from NW to E which also affects fracture intensity in the field. Few fracture sets have tendency to be slip prone even with depletion up to 300psi-800psi while others will require stimulation or acid clean up job. Eight exploration wells drilled based on the study have shown good flow rate on initial well testing in the area providing validation to the study.
{"title":"Field Scale Geo-Mechanical Analysis To Identify Fracture Sweet Spots Within Deccan Trap, Western Onshore, India","authors":"Raj Kumar, S. Mukherjee, S. K. Biswal, R. V, S. Subbiah, J. Zacharia, R. Talreja, A. Bandyopadhyay, M. Singh","doi":"10.4043/31206-ms","DOIUrl":"https://doi.org/10.4043/31206-ms","url":null,"abstract":"\u0000 Hydrocarbon exploration continues to venture into new avenues. This paper elaborates the 3D geomechanical study carried out to identify sweet spots in Deccan Trap Basalts in depth ranging from 500m-1100m in Cambay basin field of India. The main challenge is wide variation in the rock mechanical properties and stress profiles along various azimuths resulting from different tectonic incidents over the geological ages. Several drilling complications and held ups during electro logging in highly deviated wells are also reported. The normal fault tectonic framework has the imprint of two sets of faults viz., NNW-SSE and ENE-WSW. Deccan Trap acts as reservoirs due to the presence of connected open fracture network and to assess the potential reserves a comprehensive 3D Critically stressed fracture analysis has been performed using 3D numerical simulation-based rock properties, in-situ stress and seismic data. Open hole geophysical logs like sonic dipole and borehole images have been used to estimate rock mechanical properties and stress profiles in 18 key wells. Available core data of Basalt in the area have been used for dynamic to static rock properties estimation along with available published literature data. Critically stressed fracture analysis using 1D MEM outputs and dips dataset has been performed at well scale to history match production logging and testing results of 23 wells located in different fault blocks. 3D stress model has been built using plasticity model while taking into account faults and fracture sets. Utilizing 3D Geomechanical properties and Discrete fracture network model, critically stressed fracture sets have been identified across the field with slip tolerance and effective drawdown pressures. The study suggests that structurally high locations are good producers if seals are present above Trap. Sub-horizontal fractures have a higher closing tendency with decline in pressure in layers with SHmax>SHmin>Sv inside stiff Trap layer. There is variation of slip tolerance in the range of 0.2-1.4 in fracture sets which indicates slip tendency to be varying both vertically and laterally. Faults with ENE-WSW strike seem to be fluid migratory conduits and their intersection with NNW-SSE discontinuities are the areas where fracture sets have a higher slip tendency. Most of the producing layers are within 25m-55m of Trap with water being encountered at deeper depth intervals. These are mostly weathered fractured layers within the trap. The stress map suggests rotation of the maximum horizontal stress azimuth from NW to E which also affects fracture intensity in the field. Few fracture sets have tendency to be slip prone even with depletion up to 300psi-800psi while others will require stimulation or acid clean up job. Eight exploration wells drilled based on the study have shown good flow rate on initial well testing in the area providing validation to the study.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88986868","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This article will outline the development, qualification, and in-field service trial of an additively manufactured 316 stainless steel pump impeller in chloride-containing water service for approximately 9 months. The pump impeller was manufactured by a hybrid directed energy deposition (DED) process. The novel process combines 5-axis DED and machining in one setup which brings significant reductions in lead time and other flexibility when compared to conventional manufacturing methods. Further benefits and challenges will be outlined. Qualification test results including mechanical properties, corrosion resistance, and select micrographs of the material will be shown. A post-service analysis of the performance of the component is also provided. Discussion of the applicability of 3D printing to end users, creating value in rapid component delivery and innovation, is included. A forward-looking assessment of the next steps for impeller design and manufacturing with additive manufacturing is also included.
{"title":"Qualification and In-Service Performance of an Additively Manufactured Oilfield Pump Impeller","authors":"R. Rettew, David Griffiths, R. Rettberg","doi":"10.4043/30961-ms","DOIUrl":"https://doi.org/10.4043/30961-ms","url":null,"abstract":"\u0000 This article will outline the development, qualification, and in-field service trial of an additively manufactured 316 stainless steel pump impeller in chloride-containing water service for approximately 9 months. The pump impeller was manufactured by a hybrid directed energy deposition (DED) process. The novel process combines 5-axis DED and machining in one setup which brings significant reductions in lead time and other flexibility when compared to conventional manufacturing methods. Further benefits and challenges will be outlined. Qualification test results including mechanical properties, corrosion resistance, and select micrographs of the material will be shown. A post-service analysis of the performance of the component is also provided. Discussion of the applicability of 3D printing to end users, creating value in rapid component delivery and innovation, is included. A forward-looking assessment of the next steps for impeller design and manufacturing with additive manufacturing is also included.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78237080","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}
Pedro A. Romero Rojas, L. Tagarieva, S. Mohamed, Mohand Arezki Belloul, Chao Chen, Mohammed Boushari, Mahdi Nwab, Khaled Al-Hindi, Jesus Manzo
The Middle Burgan formation in North Kuwait is very challenging: its limited vertical thickness and overall low resistivity require complex and special operations for drilling, formation evaluation and completion to ensure optimum production. The objective of this case study is to demonstrate the value of Nuclear Magnetic Resonance (NMR) log data to provide rock quality and fluid typing in this challenging environment, where conventional logs are not enough for reservoir understanding along a horizontal well. A horizontal 6 1/8" section was drilled through the Middle Burgan formation with oil-based mud and Gamma Ray, Resistivity, Density data were acquired while drilling, and data from the latest generation of multifrequency, focused NMR wireline tool (FMR), conveyed on pipe (PCL). Water saturation computation in low resistivity pay often exceeds the real value when computed using conventional logs. In this environment, NMR logging proved to be essential for the proper reservoir characterization and to support critical decisions on well completion design. Fundamental rock quality and permeability profiles were supplied by NMR. Oil saturation was identified by applying the 2D-NMR methods, Diffusion vs. T2, or DT2 maps. Despite the presence of washouts, high quality NMR data was obtained at different depths of investigation in the horizontal well section. Integrating the NMR data with conventional well logs helped advanced reservoir characterization, in reducing the uncertainty in formation evaluation by clearly identifying pay and shale zones, and furthermore, in providing necessary information to support management decisions regarding fracking design to maximize oil production. The formation evaluation and well objectives were met with the aid of the high-quality NMR log data. The multifrequency capability of the tool allows data acquisition at different depths of investigation which helped to overcome the negative effects of washouts in the data interpretation. A remarkable well performance and high productivity from the low resistivity, thin reservoir layers, is expected based on decisions made from the by very reliable well log data interpretation.
{"title":"Pipe Conveyed NMR Logging Secures Successful Reservoir Characterization in a Low Resistivity Pay","authors":"Pedro A. Romero Rojas, L. Tagarieva, S. Mohamed, Mohand Arezki Belloul, Chao Chen, Mohammed Boushari, Mahdi Nwab, Khaled Al-Hindi, Jesus Manzo","doi":"10.4043/30931-ms","DOIUrl":"https://doi.org/10.4043/30931-ms","url":null,"abstract":"\u0000 The Middle Burgan formation in North Kuwait is very challenging: its limited vertical thickness and overall low resistivity require complex and special operations for drilling, formation evaluation and completion to ensure optimum production. The objective of this case study is to demonstrate the value of Nuclear Magnetic Resonance (NMR) log data to provide rock quality and fluid typing in this challenging environment, where conventional logs are not enough for reservoir understanding along a horizontal well.\u0000 A horizontal 6 1/8\" section was drilled through the Middle Burgan formation with oil-based mud and Gamma Ray, Resistivity, Density data were acquired while drilling, and data from the latest generation of multifrequency, focused NMR wireline tool (FMR), conveyed on pipe (PCL). Water saturation computation in low resistivity pay often exceeds the real value when computed using conventional logs. In this environment, NMR logging proved to be essential for the proper reservoir characterization and to support critical decisions on well completion design. Fundamental rock quality and permeability profiles were supplied by NMR. Oil saturation was identified by applying the 2D-NMR methods, Diffusion vs. T2, or DT2 maps.\u0000 Despite the presence of washouts, high quality NMR data was obtained at different depths of investigation in the horizontal well section. Integrating the NMR data with conventional well logs helped advanced reservoir characterization, in reducing the uncertainty in formation evaluation by clearly identifying pay and shale zones, and furthermore, in providing necessary information to support management decisions regarding fracking design to maximize oil production.\u0000 The formation evaluation and well objectives were met with the aid of the high-quality NMR log data. The multifrequency capability of the tool allows data acquisition at different depths of investigation which helped to overcome the negative effects of washouts in the data interpretation. A remarkable well performance and high productivity from the low resistivity, thin reservoir layers, is expected based on decisions made from the by very reliable well log data interpretation.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"41 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83848355","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}
Lost circulation (LC), commonly encountered in drilling and cementing operations, can be a costly problem that increases non-productive time, especially in highly permeable formations. When LC occurs during cementing, zonal isolation can be compromised. Risks associated with LC affect most applications, including offshore operations. This paper presents the evaluation of a new tailored spacer system (TSS) designed to effectively mitigate LC and its use in deepwater cementing operations to meet zonal isolation objectives.
{"title":"Lost Circulation Risk Mitigation in Deepwater Cementing Operations with a New Tailored Spacer System","authors":"Angela Gorman, Sandip P Patil, K. Agapiou","doi":"10.4043/31091-ms","DOIUrl":"https://doi.org/10.4043/31091-ms","url":null,"abstract":"\u0000 Lost circulation (LC), commonly encountered in drilling and cementing operations, can be a costly problem that increases non-productive time, especially in highly permeable formations. When LC occurs during cementing, zonal isolation can be compromised. Risks associated with LC affect most applications, including offshore operations. This paper presents the evaluation of a new tailored spacer system (TSS) designed to effectively mitigate LC and its use in deepwater cementing operations to meet zonal isolation objectives.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78246661","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}
Shaktim Dutta, Kamaljeet Singh, G. Agrawal, Apoorva Kumar
Multiple leaks in production tubing of deep wells can be efficiently identified using fiber-optic distributed temperature measurement and thereby mitigating the health, safety and environment (HSE) risk associated with a potential well barrier failure. Further, a production log can be used to gain more insight and finalize a way ahead to resolve the issues of the well integrity. An innovative solution-driven approach was identified with fiber-optic distributed measurement playing a key role. Multiple leaks were suspected in the production system and a fiber-optic cable was run to identify possible areas of leak path. In these deep wells, after the fiber-optic data acquisition, a production log was recorded across selective depths to provide more insights on leak paths. Post identification of leak depths, a definitive decision between tubular patching and production system overhaul was decided based on combined outputs of fiber-optic, production log and tubular patch technology. Results are presented for a two-well operation. Taking an example of Well A, leaks were successfully identified at three depths using the novel operational approach. Further, operation time was reduced from three days (conventional production log measurement performed during daylight operation) to one day (combination of fiber-optic distributed temperature sensing and production log in a single run). Diagnosis of production system issues were completed in one flowing and one shut-in survey condition, thereby reducing the risk of HSE exposure with multiple flowing conditions (conventional production log measurement). Additional insight and confirmation on leaks were observed from production log data which helped identify the presence of a leak across the tubing body. This observation was substantial in deciding whether to proceed with tubing patch or replace the entire production tubing. Tubing patch technology was not satisfactorily recognized to provide well integrity across leak depths. Hence, the decision was made to replace the entire production tubing. The novel operational approach affirms the versatility of fiber-optic distributed temperature measurement in solving critical issues of operation time and reducing HSE exposure while delivering decisive information on production system issues. The paper serves as a staging area for other applications of similar nature to unlock even wider horizons for distributed temperature sensing.
{"title":"Unlocking the Potential of Fiber-Optic Distributed Temperature Sensing in Resolving Well Integrity Issues","authors":"Shaktim Dutta, Kamaljeet Singh, G. Agrawal, Apoorva Kumar","doi":"10.4043/30990-ms","DOIUrl":"https://doi.org/10.4043/30990-ms","url":null,"abstract":"\u0000 Multiple leaks in production tubing of deep wells can be efficiently identified using fiber-optic distributed temperature measurement and thereby mitigating the health, safety and environment (HSE) risk associated with a potential well barrier failure. Further, a production log can be used to gain more insight and finalize a way ahead to resolve the issues of the well integrity.\u0000 An innovative solution-driven approach was identified with fiber-optic distributed measurement playing a key role. Multiple leaks were suspected in the production system and a fiber-optic cable was run to identify possible areas of leak path. In these deep wells, after the fiber-optic data acquisition, a production log was recorded across selective depths to provide more insights on leak paths. Post identification of leak depths, a definitive decision between tubular patching and production system overhaul was decided based on combined outputs of fiber-optic, production log and tubular patch technology.\u0000 Results are presented for a two-well operation. Taking an example of Well A, leaks were successfully identified at three depths using the novel operational approach. Further, operation time was reduced from three days (conventional production log measurement performed during daylight operation) to one day (combination of fiber-optic distributed temperature sensing and production log in a single run). Diagnosis of production system issues were completed in one flowing and one shut-in survey condition, thereby reducing the risk of HSE exposure with multiple flowing conditions (conventional production log measurement). Additional insight and confirmation on leaks were observed from production log data which helped identify the presence of a leak across the tubing body. This observation was substantial in deciding whether to proceed with tubing patch or replace the entire production tubing. Tubing patch technology was not satisfactorily recognized to provide well integrity across leak depths. Hence, the decision was made to replace the entire production tubing.\u0000 The novel operational approach affirms the versatility of fiber-optic distributed temperature measurement in solving critical issues of operation time and reducing HSE exposure while delivering decisive information on production system issues. The paper serves as a staging area for other applications of similar nature to unlock even wider horizons for distributed temperature sensing.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79911396","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}
Adam C Jackson, Rodrigo Diaz, Heidi Svalund, Raymond Hansen, Grethe Hartviksen
Rubber based systems have been used in subsea thermal insulation for many years and have proven themselves to be reliable and cost efficient. Formulations have been changed over the years, pressing the maximum usage temperature upwards and into the realm of 160 to180°C in a hot-wet environment. Until recently there was a need for high temperature along with pressure vessels (autoclaves) for vulcanisation. This has limited the widespread use of such systems. Recent changes have eliminated the need for autoclaves, however the high temperature vulcanisation hasstill been required. A novel formulation has been developed to address these shortcomings, so that this class of materials could have wider use. This new material employs freely available materials in a unique blend. The material contains no hydrolysable groups and can operate from −40°C to 180°C continuously in air and in a hot-wet environment and retains its resilience and flexibility; and thus opening for use in both high and low temperature systems. The formulation does not include the use of hollow glass microspheres and is, correspondingly, without water depth limitations. A new, highly reliable vulcanisation chemistry allows for a stable latency time for application, with vulcanisation temperatures reduced to 50°C. This allows for rapid hand application and simultaneous vulcanisation on subsea trees, valves, manifolds, etc. The material is self-agglomerating, merging under gentle pressure, and can be applied at high thickness. As the base material has an intrinsically low thermal conductivity, glass-based fillers are not needed. The material adheres well to painted or primed surfaces and to many other materials typically used in the offshore thermal insulation industry. The 2-component material is conveniently combined on site, reducing the need for refrigeration during transport and easing mobilisation logistics and is applied using simple hand tools. Extruded profiles can be used directly on complex structures or combined into sheets for ease of application on more regular shapes in order to optimise application rates. Moulds are not required for application, reducing engineering and fabrication cost, while also shortening mobilisation time. The system has been extensively qualified according to ISO 12736 for continuous use at 180°C. This paper will detail important aspects of the development project along with the results of the qualification testing.
{"title":"Novel Elastomer Materials for Extreme Temperature Operation in Subsea Thermal Insulation Applications at Unlimited Water Depth","authors":"Adam C Jackson, Rodrigo Diaz, Heidi Svalund, Raymond Hansen, Grethe Hartviksen","doi":"10.4043/31141-ms","DOIUrl":"https://doi.org/10.4043/31141-ms","url":null,"abstract":"\u0000 Rubber based systems have been used in subsea thermal insulation for many years and have proven themselves to be reliable and cost efficient. Formulations have been changed over the years, pressing the maximum usage temperature upwards and into the realm of 160 to180°C in a hot-wet environment. Until recently there was a need for high temperature along with pressure vessels (autoclaves) for vulcanisation. This has limited the widespread use of such systems. Recent changes have eliminated the need for autoclaves, however the high temperature vulcanisation hasstill been required.\u0000 A novel formulation has been developed to address these shortcomings, so that this class of materials could have wider use. This new material employs freely available materials in a unique blend. The material contains no hydrolysable groups and can operate from −40°C to 180°C continuously in air and in a hot-wet environment and retains its resilience and flexibility; and thus opening for use in both high and low temperature systems. The formulation does not include the use of hollow glass microspheres and is, correspondingly, without water depth limitations. A new, highly reliable vulcanisation chemistry allows for a stable latency time for application, with vulcanisation temperatures reduced to 50°C. This allows for rapid hand application and simultaneous vulcanisation on subsea trees, valves, manifolds, etc. The material is self-agglomerating, merging under gentle pressure, and can be applied at high thickness. As the base material has an intrinsically low thermal conductivity, glass-based fillers are not needed. The material adheres well to painted or primed surfaces and to many other materials typically used in the offshore thermal insulation industry.\u0000 The 2-component material is conveniently combined on site, reducing the need for refrigeration during transport and easing mobilisation logistics and is applied using simple hand tools. Extruded profiles can be used directly on complex structures or combined into sheets for ease of application on more regular shapes in order to optimise application rates. Moulds are not required for application, reducing engineering and fabrication cost, while also shortening mobilisation time.\u0000 The system has been extensively qualified according to ISO 12736 for continuous use at 180°C. This paper will detail important aspects of the development project along with the results of the qualification testing.","PeriodicalId":11072,"journal":{"name":"Day 1 Mon, August 16, 2021","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79025515","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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