F. Silva, C. Beneduzi, Gabriel Feres Nassau, T. B. Rossi
The main goal of this work was to estimate carbonate porosity from sonic log S-wave slowness measurement, practically insensitive to fluid effect. Methodology is empirical and had already been successfully tested in sandstones (Silva and Beneduzi (2018)). Oolitic carbonate reservoir log data were used and porosity is in good agreement with lab data. Small deviations were observed in more heterogeneous carbonate systems mainly composed by stromatolites or bivalves, being interpreted as porous geometry influence. Compressional velocity deviation log methodology (Eberli et al., 2003) is currently used to identify porosity type in carbonates. The present rock physics model used to estimate porosity allows to define shear velocity deviations. Combination between Vp (P-wave velocity) and Vs (S-wave velocity) deviation (Vp/Vs deviation log) shows good compatibility with flow zones. A significant linear correlation was observed between new deviation curve and the lab values, allowing calculate permeability for the entire well. Results are in good agreement with NMR log permeability. New method brings up important reservoir petrophysical information. Moreover, the results can give a very important technical support in the early stages of well evaluation.
这项工作的主要目标是通过声波测井s波慢度测量来估计碳酸盐孔隙度，实际上对流体影响不敏感。方法是经验的，并且已经在砂岩中成功地进行了测试(Silva和Beneduzi(2018))。利用鲕状碳酸盐岩储层测井资料，孔隙度与实验室数据吻合较好。在主要由叠层石或双壳类组成的非均质碳酸盐体系中观察到较小的偏差，这被解释为孔隙几何形状的影响。压缩速度偏差测井方法(Eberli et al.， 2003)目前被用于识别碳酸盐岩孔隙类型。目前用于估计孔隙度的岩石物理模型允许定义剪切速度偏差。Vp(纵波速度)和Vs(横波速度)偏差组合(Vp/Vs偏差测井)与流区具有较好的相容性。新的井斜曲线与实验值之间存在显著的线性相关性，从而可以计算出整口井的渗透率。结果与核磁共振测井渗透率吻合较好。新方法提供了重要的储层岩石物性信息。此外，该结果可为井评的早期阶段提供非常重要的技术支持。
{"title":"Carbonate Porosity and Permeability from Sonic Log","authors":"F. Silva, C. Beneduzi, Gabriel Feres Nassau, T. B. Rossi","doi":"10.4043/29782-ms","DOIUrl":"https://doi.org/10.4043/29782-ms","url":null,"abstract":"\u0000 The main goal of this work was to estimate carbonate porosity from sonic log S-wave slowness measurement, practically insensitive to fluid effect. Methodology is empirical and had already been successfully tested in sandstones (Silva and Beneduzi (2018)).\u0000 Oolitic carbonate reservoir log data were used and porosity is in good agreement with lab data. Small deviations were observed in more heterogeneous carbonate systems mainly composed by stromatolites or bivalves, being interpreted as porous geometry influence.\u0000 Compressional velocity deviation log methodology (Eberli et al., 2003) is currently used to identify porosity type in carbonates. The present rock physics model used to estimate porosity allows to define shear velocity deviations. Combination between Vp (P-wave velocity) and Vs (S-wave velocity) deviation (Vp/Vs deviation log) shows good compatibility with flow zones.\u0000 A significant linear correlation was observed between new deviation curve and the lab values, allowing calculate permeability for the entire well. Results are in good agreement with NMR log permeability. New method brings up important reservoir petrophysical information. Moreover, the results can give a very important technical support in the early stages of well evaluation.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"2017 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84905862","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 work aims to present a review of dielectric logging, including physical principles, petrophysical evaluation, and applications. In addition, we will present a history of its use in Petrobras oilfields. The dielectric properties are generated by the charge alignment created by an excitation provided by an electric field. In this sense, polar characteristics of water molecules allow quantification of volume of water present in the reservoir, independently of salinity. Owing to the shallow depths of investigation, dielectric tools are useful in evaluating residual oil in high uncertainty salinity conditions, especially in mature fields, where uncertainties occur due to injection of water and/or steam. Although this logging tool has a long history of use in the petroleum industry, it was rarely used in Petrobras oilfields due to the high specificity, limitations of the technique, and/or high cost. Considering high frequencies used and proximity between electrodes, the tool provides very shallow measurements, which makes it impossible to evaluate the virgin zone in most reservoirs. Due to these characteristics, the tool was widely employed in low mobility hydrocarbon formations, where mud filtrate invasion tends to be smaller. The dielectric tool was used in Petrobras to evaluate reservoirs with very high viscosity and fresh water, in which it showed good results in the quantification of water saturation and hydrocarbon mobility. Additionally, the tool was used in Pre-salt in order to evaluate residual oil saturation to diminish the uncertain of microresistivity logs. Besides evaluating water saturation, many works have shown other applications for dielectric logging, such as to determine conductivity, salinity, wettability, Archie's "m" and "n" electric parameters, CEC, and evaluation of laminated reservoirs.
{"title":"Dielectric Logging: Principles, Applications, and Examples from the Brazilian Oilfields","authors":"R. Herlinger","doi":"10.4043/29882-ms","DOIUrl":"https://doi.org/10.4043/29882-ms","url":null,"abstract":"\u0000 This work aims to present a review of dielectric logging, including physical principles, petrophysical evaluation, and applications. In addition, we will present a history of its use in Petrobras oilfields. The dielectric properties are generated by the charge alignment created by an excitation provided by an electric field. In this sense, polar characteristics of water molecules allow quantification of volume of water present in the reservoir, independently of salinity. Owing to the shallow depths of investigation, dielectric tools are useful in evaluating residual oil in high uncertainty salinity conditions, especially in mature fields, where uncertainties occur due to injection of water and/or steam.\u0000 Although this logging tool has a long history of use in the petroleum industry, it was rarely used in Petrobras oilfields due to the high specificity, limitations of the technique, and/or high cost. Considering high frequencies used and proximity between electrodes, the tool provides very shallow measurements, which makes it impossible to evaluate the virgin zone in most reservoirs. Due to these characteristics, the tool was widely employed in low mobility hydrocarbon formations, where mud filtrate invasion tends to be smaller. The dielectric tool was used in Petrobras to evaluate reservoirs with very high viscosity and fresh water, in which it showed good results in the quantification of water saturation and hydrocarbon mobility. Additionally, the tool was used in Pre-salt in order to evaluate residual oil saturation to diminish the uncertain of microresistivity logs.\u0000 Besides evaluating water saturation, many works have shown other applications for dielectric logging, such as to determine conductivity, salinity, wettability, Archie's \"m\" and \"n\" electric parameters, CEC, and evaluation of laminated reservoirs.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83252442","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}
Sylvain Truche, Aubin Malassagne, Raghid Aljarah, C. Saunier, M. Mínguez, A. Ulanov, P. T. Moe
A new time-domain Vortex Induces Vibration (VIV) model is here proposed and applied to modelling of drilling riser and wellhead fatigue. The model challenges the industry best practices for VIV predictions which are known to be conservative. The paper is divided in two main parts. The first part is devoted to a validation process considering a rigorous benchmark with the ExxonMobil database. The second part treats the application of the model to a study of a drilling riser configuration. In both parts the proposed time domain model is compared to the industry best practice representated by SHEAR7 v4.10. The model development has been driven by project requirements. It carefully balances CPU consumption and targeted / required accuracy. The model is based on a hybrid approach integrating concepts from both frequential model and existing time domain wake oscillators. It consists of a hydrodynamic solver capable of balancing both Vortex Induced Excitation and Hydrodynamic Damping at each predetermined node along the mechanical model. The solver is then coupled with a Finite Element (FE) model (or equivalent) to assess the resulting riser dynamics. The different nonlinearities of the riser model (e.g. soil, riser flexible joint) can consequently be accounted for in the usual manner for the global riser analysis. The proposed model is first benchmarked using a reference database. The model produces riser responses that match well for both uniform and shear current conditions. Results obtained from the proposed model are also compared to results obtained from SHEAR7 with different choices of parameters (including the recommended values). Although mode shapes are in good agreement, the conservatism of the latter is demonstrated and challenged by the proposed model which appears to be a promising candidate for VIV analysis. A nonlinear model of a 400m long drilling riser is considered as the use case. The VIV analysis is first performed using SHEAR7 and a linearized version of the riser model. The results are compared to those obtained for the proposed time-domain model with the same linearized drilling riser model. While the two approaches again produce the same mode shapes, the proposed model produces much less conservative results (approx 50% reduction of the vibration amplitude). Finally, the different nonlinearities of the riser model (wellhead, riser flexible joint) are considered to assess their possible impact on global riser behavior and local impact (i.e. at well head). Depending on the nonlinearities to be considered, the local impact of the model is clearly demonstrated.
{"title":"Non-Linear Time Domain Drilling Riser VIV Modelling","authors":"Sylvain Truche, Aubin Malassagne, Raghid Aljarah, C. Saunier, M. Mínguez, A. Ulanov, P. T. Moe","doi":"10.4043/29813-ms","DOIUrl":"https://doi.org/10.4043/29813-ms","url":null,"abstract":"\u0000 A new time-domain Vortex Induces Vibration (VIV) model is here proposed and applied to modelling of drilling riser and wellhead fatigue. The model challenges the industry best practices for VIV predictions which are known to be conservative. The paper is divided in two main parts. The first part is devoted to a validation process considering a rigorous benchmark with the ExxonMobil database. The second part treats the application of the model to a study of a drilling riser configuration. In both parts the proposed time domain model is compared to the industry best practice representated by SHEAR7 v4.10.\u0000 The model development has been driven by project requirements. It carefully balances CPU consumption and targeted / required accuracy. The model is based on a hybrid approach integrating concepts from both frequential model and existing time domain wake oscillators. It consists of a hydrodynamic solver capable of balancing both Vortex Induced Excitation and Hydrodynamic Damping at each predetermined node along the mechanical model. The solver is then coupled with a Finite Element (FE) model (or equivalent) to assess the resulting riser dynamics. The different nonlinearities of the riser model (e.g. soil, riser flexible joint) can consequently be accounted for in the usual manner for the global riser analysis.\u0000 The proposed model is first benchmarked using a reference database. The model produces riser responses that match well for both uniform and shear current conditions. Results obtained from the proposed model are also compared to results obtained from SHEAR7 with different choices of parameters (including the recommended values). Although mode shapes are in good agreement, the conservatism of the latter is demonstrated and challenged by the proposed model which appears to be a promising candidate for VIV analysis.\u0000 A nonlinear model of a 400m long drilling riser is considered as the use case. The VIV analysis is first performed using SHEAR7 and a linearized version of the riser model. The results are compared to those obtained for the proposed time-domain model with the same linearized drilling riser model. While the two approaches again produce the same mode shapes, the proposed model produces much less conservative results (approx 50% reduction of the vibration amplitude).\u0000 Finally, the different nonlinearities of the riser model (wellhead, riser flexible joint) are considered to assess their possible impact on global riser behavior and local impact (i.e. at well head). Depending on the nonlinearities to be considered, the local impact of the model is clearly demonstrated.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87752418","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}
Thermoplastic Composite Pipe (TCP) has a solid wall construction constituted from a single polymer material with embedded (melt-fused) fibre reinforcements. It is a disruptive technology where all the advantages for ultra-deep water developments come together: high strength, light weight, corrosion free, low CAPEX, etc. TCP is therefore one of the most promising solutions to overcome the recent failures found on pre-salt fields related to corrosion under high concentrations of H2S and CO2. However, introducing a new technology on very challenging applications such as deep water production risers, requires careful consideration and mitigation of all technical and project execution risks. This paper starts presenting a historical review of some of the new technologies applied offshore Brazil over the last 20 years making a parallel with the increasing acceptance of Thermoplastic Composite Pipe in the Brazilian market. Following the historical review, TCP technology is presented and strategy to enable free hanging catenary systems for ultra-deep water environments discussed. The basis of the study is a typical offshore Brazil pre-salt field and feasibility of 6" and 8" free hanging TCP risers were assessed. Study was performed in close cooperation with a major operator and an installation contractor in Brazil. Global, installation and local analyses of the TCP Riser system have shown the feasibility of installation as well as operations in a free hanging catenary configuration throughout the 30 years' service life. In 2017, this pre-FEED study was used as basis for a FMECA (Failure mode, Effects and Criticality Analysis). The FMECA exercise was carried out together with a third-party certification body and two major Oil & Gas companies very active in Brazil. A detailed business case study was performed in order to quantify the potential CAPEX savings that TCP technology can bring compared to the low lazy wave systems currently installed in pre-salt fields, offshore Brazil. Result is that if TCP is adopted as primary technology for Risers&Flowlines, significant savings are expected. Savings comes both from pipe and ancillary's procurement costs since TCP technology enables free hanging catenary configuration, avoiding purchase of expensive buoyancy modules. The outcome of this work lead to a qualification program currently being sponsored by one major operator active in Brazil. Technology Roadmap was established in phases being the ultimate goal the qualification of pre-salt 8.0in production lines. Reasons for adopting this qualification strategy is presented. The qualification is driven by DNV-ST-F-119, a dedicated standard for TCP design and qualification.
{"title":"Thermoplastic Composite Pipes: A Reliable Cost-Effective Solution for Pre-salt","authors":"T. Barbosa, R. Bastos, H. Boer, R. Rojas-Díaz","doi":"10.4043/29819-ms","DOIUrl":"https://doi.org/10.4043/29819-ms","url":null,"abstract":"\u0000 Thermoplastic Composite Pipe (TCP) has a solid wall construction constituted from a single polymer material with embedded (melt-fused) fibre reinforcements. It is a disruptive technology where all the advantages for ultra-deep water developments come together: high strength, light weight, corrosion free, low CAPEX, etc. TCP is therefore one of the most promising solutions to overcome the recent failures found on pre-salt fields related to corrosion under high concentrations of H2S and CO2.\u0000 However, introducing a new technology on very challenging applications such as deep water production risers, requires careful consideration and mitigation of all technical and project execution risks.\u0000 This paper starts presenting a historical review of some of the new technologies applied offshore Brazil over the last 20 years making a parallel with the increasing acceptance of Thermoplastic Composite Pipe in the Brazilian market.\u0000 Following the historical review, TCP technology is presented and strategy to enable free hanging catenary systems for ultra-deep water environments discussed.\u0000 The basis of the study is a typical offshore Brazil pre-salt field and feasibility of 6\" and 8\" free hanging TCP risers were assessed. Study was performed in close cooperation with a major operator and an installation contractor in Brazil. Global, installation and local analyses of the TCP Riser system have shown the feasibility of installation as well as operations in a free hanging catenary configuration throughout the 30 years' service life. In 2017, this pre-FEED study was used as basis for a FMECA (Failure mode, Effects and Criticality Analysis). The FMECA exercise was carried out together with a third-party certification body and two major Oil & Gas companies very active in Brazil.\u0000 A detailed business case study was performed in order to quantify the potential CAPEX savings that TCP technology can bring compared to the low lazy wave systems currently installed in pre-salt fields, offshore Brazil. Result is that if TCP is adopted as primary technology for Risers&Flowlines, significant savings are expected. Savings comes both from pipe and ancillary's procurement costs since TCP technology enables free hanging catenary configuration, avoiding purchase of expensive buoyancy modules.\u0000 The outcome of this work lead to a qualification program currently being sponsored by one major operator active in Brazil. Technology Roadmap was established in phases being the ultimate goal the qualification of pre-salt 8.0in production lines. Reasons for adopting this qualification strategy is presented. The qualification is driven by DNV-ST-F-119, a dedicated standard for TCP design and qualification.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91038333","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Oil production in ultra-deep waters places some new challenges for floating units. As an FPSO is one of most common types of production units adopted by Petrobras, its behavior in extreme conditions has to be fully tested and verified. During extreme sea storms, ship type floating structures may be subjected to water on deck events (green water). In order to allow a detailed structural analysis, Computational Fluid Dynamics (CFD) techniques may be used to investigate detailed loads due to water on deck propagation, especially in beam sea conditions, which are not traditionally covered by maritime rules. Based on model test results, water ingress and water on deck propagation are simulated through CFD analysis. The methodology adopted consists of two different approaches: (i) The influence of a riser balcony lateral extent is analyzed based on a 2D wave propagation model and; (ii) the complex flow behavior through topside equipment is discussed by using a 3D simulation of a restricted deck area, including some strategies for impact protection. The results of the simulations allow investigation of the complex flow behavior depending on the riser balcony extent and topside configuration, as well as the resulting loads on critical structures. For a side hull balcony, its protective effect against wave run-up in beam waves is only effective with a lateral extent of 8m. By performing water on deck simulations, the benefits of "V" type protections are quantified leading to 20% loading reduction when compared to flat plates. The simulations reveal CFD as a very powerful tool to assess detailed transient pressure distributions for optimized structural design.
{"title":"Detailed CFD Simulations of Green Water Flow on FPSO Deck","authors":"D. F. Silva","doi":"10.4043/29892-ms","DOIUrl":"https://doi.org/10.4043/29892-ms","url":null,"abstract":"\u0000 Oil production in ultra-deep waters places some new challenges for floating units. As an FPSO is one of most common types of production units adopted by Petrobras, its behavior in extreme conditions has to be fully tested and verified. During extreme sea storms, ship type floating structures may be subjected to water on deck events (green water). In order to allow a detailed structural analysis, Computational Fluid Dynamics (CFD) techniques may be used to investigate detailed loads due to water on deck propagation, especially in beam sea conditions, which are not traditionally covered by maritime rules.\u0000 Based on model test results, water ingress and water on deck propagation are simulated through CFD analysis. The methodology adopted consists of two different approaches: (i) The influence of a riser balcony lateral extent is analyzed based on a 2D wave propagation model and; (ii) the complex flow behavior through topside equipment is discussed by using a 3D simulation of a restricted deck area, including some strategies for impact protection.\u0000 The results of the simulations allow investigation of the complex flow behavior depending on the riser balcony extent and topside configuration, as well as the resulting loads on critical structures. For a side hull balcony, its protective effect against wave run-up in beam waves is only effective with a lateral extent of 8m. By performing water on deck simulations, the benefits of \"V\" type protections are quantified leading to 20% loading reduction when compared to flat plates.\u0000 The simulations reveal CFD as a very powerful tool to assess detailed transient pressure distributions for optimized structural design.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"16 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84823537","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}
T. S. Kathayat, Richard Hill, P. Thakor, R. Goyal, Ankit Singh
Recent use of thick wall pipelines for the transmission of extreme sour hydrocar bons in deep and ultra- deep water has required the confirmation of resistance to environmental cracking. This paper presents a comprehensive test program conducted on 30 inch outside diameter and 38.7 mm wall thickness, ISO 3183 L415MS / L415MO PSL2 line pipe to establish the contribution of plate and pipe properties and process parameters on the environmental cracking resistance. The JCOE forming technology was used to prepare the test pipes for evaluating the influence of isolated surface hardness zones on the initiation and propagation of Hydrogen Induced Cracking (HIC) and Sulfide Stress Corrosion Cracking (SSCC). Detailed technical requirements for plate supply included but was not limited to the development of alloy design, steel melting and continuous casting parameters as well as plate rolling and accelerated cooling process control limits. The test program covered the contribution of various stages of pipe production such as forming, welding, and mechanical cold expansion, on fracture toughness (KIC, KISSC and CTOD), HIC and SSCC resistance. The pipe was tested in the as-manufactured, aged, and aged+1% strained conditions. Pipe dimension conformance was verified using the Automatic Pipe Dimension Measurement System (APDMS). The reliability of eddy current inspection for the detection of isolated hard zones was included in the program.
{"title":"Understanding the Behavior of Surface Hardness Hard Spots of Plate and Pipe :Extensive Test Program","authors":"T. S. Kathayat, Richard Hill, P. Thakor, R. Goyal, Ankit Singh","doi":"10.4043/29845-ms","DOIUrl":"https://doi.org/10.4043/29845-ms","url":null,"abstract":"\u0000 Recent use of thick wall pipelines for the transmission of extreme sour hydrocar bons in deep and ultra- deep water has required the confirmation of resistance to environmental cracking. This paper presents a comprehensive test program conducted on 30 inch outside diameter and 38.7 mm wall thickness, ISO 3183 L415MS / L415MO PSL2 line pipe to establish the contribution of plate and pipe properties and process parameters on the environmental cracking resistance.\u0000 The JCOE forming technology was used to prepare the test pipes for evaluating the influence of isolated surface hardness zones on the initiation and propagation of Hydrogen Induced Cracking (HIC) and Sulfide Stress Corrosion Cracking (SSCC). Detailed technical requirements for plate supply included but was not limited to the development of alloy design, steel melting and continuous casting parameters as well as plate rolling and accelerated cooling process control limits.\u0000 The test program covered the contribution of various stages of pipe production such as forming, welding, and mechanical cold expansion, on fracture toughness (KIC, KISSC and CTOD), HIC and SSCC resistance. The pipe was tested in the as-manufactured, aged, and aged+1% strained conditions. Pipe dimension conformance was verified using the Automatic Pipe Dimension Measurement System (APDMS).\u0000 The reliability of eddy current inspection for the detection of isolated hard zones was included in the program.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85365201","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 work aims to perform a comparison of depth imaging results using values not commonly used for source and receiver intervals to prove that it is possible to obtain good results, in terms of the quality of seismic sections, with less data, which can significantly reduce petroleum exploration costs. Bidimensional acoustic modeling with a finite difference scheme was applied to a slice of the 3D SEG/EAGE Overthrust model to generate the synthetic seismograms. These seismograms were generated comparing 25 m for shot and receiver intervals, which is a common interval for a seismic acquisition process, with 200 m for shot and receiver intervals, which is not a common value. A reverse time migration (RTM) technique was applied to perform the depth migration of the generated pre-stack seismic data, and the migrated shots were stacked to create the seismic section. In addition, suggestions related to seismic illumination studies and visibility analyses are discussed to improve the results and to contribute to exploration and production (E&P) cost reduction. In these cases, the SEG/EAGE Salt Dome model and the Sigsbee model from the SMAART JV project were used to illustrate the discussion.
{"title":"Depth Imaging of Complex Geological Structures using the RTM Technique in Order to Reduce Exploration Costs","authors":"Mitchel Xavier","doi":"10.4043/29893-ms","DOIUrl":"https://doi.org/10.4043/29893-ms","url":null,"abstract":"\u0000 This work aims to perform a comparison of depth imaging results using values not commonly used for source and receiver intervals to prove that it is possible to obtain good results, in terms of the quality of seismic sections, with less data, which can significantly reduce petroleum exploration costs. Bidimensional acoustic modeling with a finite difference scheme was applied to a slice of the 3D SEG/EAGE Overthrust model to generate the synthetic seismograms. These seismograms were generated comparing 25 m for shot and receiver intervals, which is a common interval for a seismic acquisition process, with 200 m for shot and receiver intervals, which is not a common value. A reverse time migration (RTM) technique was applied to perform the depth migration of the generated pre-stack seismic data, and the migrated shots were stacked to create the seismic section. In addition, suggestions related to seismic illumination studies and visibility analyses are discussed to improve the results and to contribute to exploration and production (E&P) cost reduction. In these cases, the SEG/EAGE Salt Dome model and the Sigsbee model from the SMAART JV project were used to illustrate the discussion.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"62 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82223126","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}
Digitalization of deepwater production facilities (floating and subsea units, risers, umbilicals, pipelines and flowlines) planning, construction, operations, and maintenance has been determined as an effective way to significantly reduce the life-cycle costs, enhance production levels, enable remote operations, improve personnel safety, and reduce environmental pollution. A digitalized production facility may require additional infrastructure (e.g., sensors) on physical facilities, computing capabilities, drones (air, underwater), communication facilities, and possibly secured access to a cloud platform with additional computing power. The Digitalization approaches used may vary among companies involved in planning, construction, installation, maintenance, and operation of facilities. To present a comprehensive overview of pioneering initiatives in Digitalization and hold discussion, a Panel Session for OTC Brasil 2019 has been organized. The panel comprises of leaders from operating companies, engineering and construction companies, topside and subsea systems suppliers, digital platform providers, class societies, and risk assessment specialists responsible for deepwater facilities development and operations.
{"title":"Digitalized Deepwater Production Facilities for South America - Challenges and Opportunities","authors":"R. Aggarwal, D. Renzi","doi":"10.4043/29944-ms","DOIUrl":"https://doi.org/10.4043/29944-ms","url":null,"abstract":"\u0000 Digitalization of deepwater production facilities (floating and subsea units, risers, umbilicals, pipelines and flowlines) planning, construction, operations, and maintenance has been determined as an effective way to significantly reduce the life-cycle costs, enhance production levels, enable remote operations, improve personnel safety, and reduce environmental pollution. A digitalized production facility may require additional infrastructure (e.g., sensors) on physical facilities, computing capabilities, drones (air, underwater), communication facilities, and possibly secured access to a cloud platform with additional computing power.\u0000 The Digitalization approaches used may vary among companies involved in planning, construction, installation, maintenance, and operation of facilities. To present a comprehensive overview of pioneering initiatives in Digitalization and hold discussion, a Panel Session for OTC Brasil 2019 has been organized. The panel comprises of leaders from operating companies, engineering and construction companies, topside and subsea systems suppliers, digital platform providers, class societies, and risk assessment specialists responsible for deepwater facilities development and operations.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"142 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77865439","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}
Paula Maria Nogueira Camargos, Letícia Moreira Albuquerque, H. C. Saad
Gas flaring is the controlled burning of natural gas that cannot be processed for sale or use because of technical or economic reasons. This operation is directly associated with CO2 emission and waste of energy source. As the reduction of CO2 footprint became a matter of great concern in the world, Government of diverse countries has created different strategies to mitigate the issue. For this reason, authorities use Legislation as the main tool to limit the volume of gas flaring. In Brazil, National Agency of Petroleum, Natural Gas and Biofuels (ANP) is the regulatory body responsible for regulate the natural gas flaring and venting. The instrument used is the PORTARIA ANP N° 249, published on November 1st, 2000. However, the Brazilian industry has dramatically changed after the producing starting of pre-salt fields, pointing out the necessity of the ordinance revision. After analyzing the gas flaring data from FPSOs before the gas injection start, it is suggested the adoption some guidelines for gas commissioning phase for offshore units. It is also highlighted the effectiveness of CO2 taxation in Norway as well as the possibility of zero routine flare technology implementation. Finally, to achieve lower gas flaring numbers is essentially the development of politics to make economically feasible the use of all waste gas to produce energy.
{"title":"Brazil Natural Gas Flaring and Its Regulatory Regime","authors":"Paula Maria Nogueira Camargos, Letícia Moreira Albuquerque, H. C. Saad","doi":"10.4043/29702-ms","DOIUrl":"https://doi.org/10.4043/29702-ms","url":null,"abstract":"\u0000 Gas flaring is the controlled burning of natural gas that cannot be processed for sale or use because of technical or economic reasons. This operation is directly associated with CO2 emission and waste of energy source. As the reduction of CO2 footprint became a matter of great concern in the world, Government of diverse countries has created different strategies to mitigate the issue. For this reason, authorities use Legislation as the main tool to limit the volume of gas flaring. In Brazil, National Agency of Petroleum, Natural Gas and Biofuels (ANP) is the regulatory body responsible for regulate the natural gas flaring and venting. The instrument used is the PORTARIA ANP N° 249, published on November 1st, 2000. However, the Brazilian industry has dramatically changed after the producing starting of pre-salt fields, pointing out the necessity of the ordinance revision. After analyzing the gas flaring data from FPSOs before the gas injection start, it is suggested the adoption some guidelines for gas commissioning phase for offshore units. It is also highlighted the effectiveness of CO2 taxation in Norway as well as the possibility of zero routine flare technology implementation. Finally, to achieve lower gas flaring numbers is essentially the development of politics to make economically feasible the use of all waste gas to produce energy.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"605 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77449523","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}
Jose Sergio de Araujo Cavalcante Filho, J. Pizarro
The displacement of a given fluid by another in a porous media can occur either in miscible or immiscible conditions. An immiscible displacement happens, for instance, when water displaces oil in a reservoir. It can also occur when the displacing fluid is a gas, if the interfacial tension with the oil is high enough. These processes are usually described by the fractional flow theory, which assumes isothermal flow of two immiscible and incompressible fluids in an one-dimensional, homogeneous porous media; dissipative effects, such as capillary pressure, compressibility and thermal conductivity, are neglected. Miscible floods, on the other hand, can take place in gas-oil displacements when the interfacial tension approaches zero. Common dissipative effects are fingering and dispersion, the former related to mobility ratio magnitudes and the later related to diffusion and velocity contrast commonly caused by the presence of heterogeneities. In miscible displacements through porous media, dispersion is described as the result of diffusion, local velocity gradients, streamlines dimensions in heterogeneous regions, and mechanical mixing into pores. The present work discuss these concepts and relate them to data from an actual deep offshore field. Estimates of field dispersivity by history matching tracer production profiles are based on the analytical solution for the convection-diffusion equation. Gas tracers injected and produced from wells located in the field area were evaluated assuming miscible displacement. The estimated dispersivity allowed the evaluation of mixing/spreading zones. The solution for intermittent tracer injection was used to history match tracer production data. Results shows the scale dependence of the dispersivity, which depends upon the distance and degree of heterogeneity between wells. The field scale dispersivity obtained by history match was coherent with numerical dispersion observed in a field scale numerical model. They were also compared against literature data (laboratory and field scale) in a log-log plot denoting a good agreement of present data with literature.
{"title":"Application of the Convective-Dispersive Equation to Estimate Field Scale Dispersivity based on a Field Scale Numerical Model and Tracer Production Data","authors":"Jose Sergio de Araujo Cavalcante Filho, J. Pizarro","doi":"10.4043/29736-ms","DOIUrl":"https://doi.org/10.4043/29736-ms","url":null,"abstract":"\u0000 The displacement of a given fluid by another in a porous media can occur either in miscible or immiscible conditions. An immiscible displacement happens, for instance, when water displaces oil in a reservoir. It can also occur when the displacing fluid is a gas, if the interfacial tension with the oil is high enough. These processes are usually described by the fractional flow theory, which assumes isothermal flow of two immiscible and incompressible fluids in an one-dimensional, homogeneous porous media; dissipative effects, such as capillary pressure, compressibility and thermal conductivity, are neglected. Miscible floods, on the other hand, can take place in gas-oil displacements when the interfacial tension approaches zero. Common dissipative effects are fingering and dispersion, the former related to mobility ratio magnitudes and the later related to diffusion and velocity contrast commonly caused by the presence of heterogeneities. In miscible displacements through porous media, dispersion is described as the result of diffusion, local velocity gradients, streamlines dimensions in heterogeneous regions, and mechanical mixing into pores. The present work discuss these concepts and relate them to data from an actual deep offshore field. Estimates of field dispersivity by history matching tracer production profiles are based on the analytical solution for the convection-diffusion equation. Gas tracers injected and produced from wells located in the field area were evaluated assuming miscible displacement. The estimated dispersivity allowed the evaluation of mixing/spreading zones. The solution for intermittent tracer injection was used to history match tracer production data. Results shows the scale dependence of the dispersivity, which depends upon the distance and degree of heterogeneity between wells. The field scale dispersivity obtained by history match was coherent with numerical dispersion observed in a field scale numerical model. They were also compared against literature data (laboratory and field scale) in a log-log plot denoting a good agreement of present data with literature.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81265916","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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