Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183031
C. M. D. Jesus, A. Compan, R. M. Araüjo, R. Surmas
Summary Several oil fields on the pre-salt have high heterogeneity in terms of pore types and scale, with the occurrence of non-matrix pore systems displaying important impact on productivity. Not surprisingly, discrepancies were verified between matrix permeability in 1D petrophysical models and the permeability scale estimated by DST measurements, which are generally understood as related to the presence of dissolution structures formed by karstification processes. Intending to represent the non-matrix permeability scale in our petrophysical models, Petrobras’s researchers began the development of techniques for permeability estimation, where it is possible to separate the matrix pore systems from the non-matrix and to assign different parameters to each distinct medium. This technique is known as K-image, where attributes extracted from image logs are combined with porosity logs in algorithms that calibrate the models, both with the matrix absolute permeability and DST estimated permeability, and then they are used in a permeability equation which has terms representing matrix with different flow capacities and a term that represents the extra-matrix pore systems. The application of this technique brought a significant gain in the ability to characterize permeability of non-matrix pore systems on pre-salt oil fields where the dynamic impact of these systems has been observed.
{"title":"K-Image - Permeability Characterization Integrating Matrix and Non-Matrix Pore Scales on Pre-Salt Reservoirs","authors":"C. M. D. Jesus, A. Compan, R. M. Araüjo, R. Surmas","doi":"10.3997/2214-4609.202183031","DOIUrl":"https://doi.org/10.3997/2214-4609.202183031","url":null,"abstract":"Summary Several oil fields on the pre-salt have high heterogeneity in terms of pore types and scale, with the occurrence of non-matrix pore systems displaying important impact on productivity. Not surprisingly, discrepancies were verified between matrix permeability in 1D petrophysical models and the permeability scale estimated by DST measurements, which are generally understood as related to the presence of dissolution structures formed by karstification processes. Intending to represent the non-matrix permeability scale in our petrophysical models, Petrobras’s researchers began the development of techniques for permeability estimation, where it is possible to separate the matrix pore systems from the non-matrix and to assign different parameters to each distinct medium. This technique is known as K-image, where attributes extracted from image logs are combined with porosity logs in algorithms that calibrate the models, both with the matrix absolute permeability and DST estimated permeability, and then they are used in a permeability equation which has terms representing matrix with different flow capacities and a term that represents the extra-matrix pore systems. The application of this technique brought a significant gain in the ability to characterize permeability of non-matrix pore systems on pre-salt oil fields where the dynamic impact of these systems has been observed.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87531221","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183040
L. D. Figueiredo, B. B. Rodrigues, D. Grana, M. Roisenberg
Summary In this work we apply a Bayesian framework for the joint estimation of facies and elastic properties from seismic data. The statistical model accounts for three-dimensional spatial correlation. Due to the high dimension of the problem, the algorithm is based on a MCMC method for drawing multiple realizations of the reservoir properties. The main objective of this work is to evaluate the capability of the algorithm to distinguish the different carbonate facies. The method is applied to a large seismic data set of Lula field along with six wells used to define the prior distributions and to evaluate the inversion results.
{"title":"Bayesian Seismic Inversion for the Joint Estimation of Facies and Elastic Properties of the Lula Field","authors":"L. D. Figueiredo, B. B. Rodrigues, D. Grana, M. Roisenberg","doi":"10.3997/2214-4609.202183040","DOIUrl":"https://doi.org/10.3997/2214-4609.202183040","url":null,"abstract":"Summary In this work we apply a Bayesian framework for the joint estimation of facies and elastic properties from seismic data. The statistical model accounts for three-dimensional spatial correlation. Due to the high dimension of the problem, the algorithm is based on a MCMC method for drawing multiple realizations of the reservoir properties. The main objective of this work is to evaluate the capability of the algorithm to distinguish the different carbonate facies. The method is applied to a large seismic data set of Lula field along with six wells used to define the prior distributions and to evaluate the inversion results.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88358533","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183039
C. Hughes, B. Darby
Summary Evaluating footwall carbonate geometries in concert with fault displacement and the flexural isostatic response to fault displacement, i.e. footwall uplift, can help improve prediction of reservoir presence, facies distribution, and non-matrix permeability. Large-scale faulting can produce footwall highs that are exposed and eroded as fault displacement increases, forming beveled exposure surfaces that may promote development of non-matrix permeability by processes such as meteoric karsting. Structural-stratigraphic analysis focusing on the relationship between faulting, carbonate deposition, and changes in lake level was conducted at a field in the Santos basin to aide in understanding recent and upcoming well results as well as development optimization of existing pre-salt assets. We applied concepts relating fault displacement and lake level to footwall carbonate geometries, fundamental structural mapping and analysis, and forward isostatic modelling to the field. Accommodation changes at the field scale correspond to changes in footwall uplift through time along strike of the field. Zones of high fault displacement are associated with beveled highs in the footwall, which represent exposure surfaces and thus may be prone to meteoric karsting. Fault displacement and carbonate geometry mapping helps to reduce uncertainty in possible non-matrix permeability by reducing uncertainty in lateral variability of these exposure surfaces.
{"title":"Impact of Fault Displacement on Syn-Extensional Carbonate Deposition and Excess Permeability","authors":"C. Hughes, B. Darby","doi":"10.3997/2214-4609.202183039","DOIUrl":"https://doi.org/10.3997/2214-4609.202183039","url":null,"abstract":"Summary Evaluating footwall carbonate geometries in concert with fault displacement and the flexural isostatic response to fault displacement, i.e. footwall uplift, can help improve prediction of reservoir presence, facies distribution, and non-matrix permeability. Large-scale faulting can produce footwall highs that are exposed and eroded as fault displacement increases, forming beveled exposure surfaces that may promote development of non-matrix permeability by processes such as meteoric karsting. Structural-stratigraphic analysis focusing on the relationship between faulting, carbonate deposition, and changes in lake level was conducted at a field in the Santos basin to aide in understanding recent and upcoming well results as well as development optimization of existing pre-salt assets. We applied concepts relating fault displacement and lake level to footwall carbonate geometries, fundamental structural mapping and analysis, and forward isostatic modelling to the field. Accommodation changes at the field scale correspond to changes in footwall uplift through time along strike of the field. Zones of high fault displacement are associated with beveled highs in the footwall, which represent exposure surfaces and thus may be prone to meteoric karsting. Fault displacement and carbonate geometry mapping helps to reduce uncertainty in possible non-matrix permeability by reducing uncertainty in lateral variability of these exposure surfaces.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76955002","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183003
A. Konstantinou, D. Gombosi, E. Kneller, G. Karner
Summary In this talk, we will demonstrate that the common assumptions of brine depth, salt paleotopography and desiccation cycles during salt deposition are inconsistent with the observations from the Mediterranean and South Atlantic salt basins. We propose an ultra-deep basin, ultra-deep (g750 m) brine model for these salt giants and demonstrate using numerical modeling that Dynamic Inflow and Evaporation is a favorable mechanism to generate them. These insights can help us reconcile the paleogeography of the basins during and before salt deposition, which could have significant impact on interpreting the environment of deposition of pre-salt strata.
{"title":"Forming Giant Salt Deposits in Ultra-Deep Brine Settings by Dynamic Inflow and Evaporation: The Aptian South Atlantic Example","authors":"A. Konstantinou, D. Gombosi, E. Kneller, G. Karner","doi":"10.3997/2214-4609.202183003","DOIUrl":"https://doi.org/10.3997/2214-4609.202183003","url":null,"abstract":"Summary In this talk, we will demonstrate that the common assumptions of brine depth, salt paleotopography and desiccation cycles during salt deposition are inconsistent with the observations from the Mediterranean and South Atlantic salt basins. We propose an ultra-deep basin, ultra-deep (g750 m) brine model for these salt giants and demonstrate using numerical modeling that Dynamic Inflow and Evaporation is a favorable mechanism to generate them. These insights can help us reconcile the paleogeography of the basins during and before salt deposition, which could have significant impact on interpreting the environment of deposition of pre-salt strata.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"60 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76551287","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183008
F. Vizeu, E.R.D. Oliveira Neto, A. Freire, W. Lupinacci
Summary Automatic seismic interpretation is one of the main applications of machine learning for exploration geophysics. In recent years, an increase in the popularity of convolutional neural networks to perform interpretation related tasks has been observed. Here we develop and train a 3D Convolutional Neural Network for predicting igneous seismic facies in the Santos Basin Pre-Salt. Often one of the main challenges regarding automatic seismic interpretation using neural networks relates to the scarcity or lack of training data. To overcome this problem, we used a sampling strategy to train the network with just a few partially interpreted sections. After the training process, the network was applied in the full seismic amplitude volume, outputting the igneous facies probability for the whole area. The results show good conformity with the input manual interpretation and with well logs, which was not part of the training.
{"title":"Convolutional Neural Network for Prediction of Igneous Seismic Facies in the Santos Basin Pre-Salt","authors":"F. Vizeu, E.R.D. Oliveira Neto, A. Freire, W. Lupinacci","doi":"10.3997/2214-4609.202183008","DOIUrl":"https://doi.org/10.3997/2214-4609.202183008","url":null,"abstract":"Summary Automatic seismic interpretation is one of the main applications of machine learning for exploration geophysics. In recent years, an increase in the popularity of convolutional neural networks to perform interpretation related tasks has been observed. Here we develop and train a 3D Convolutional Neural Network for predicting igneous seismic facies in the Santos Basin Pre-Salt. Often one of the main challenges regarding automatic seismic interpretation using neural networks relates to the scarcity or lack of training data. To overcome this problem, we used a sampling strategy to train the network with just a few partially interpreted sections. After the training process, the network was applied in the full seismic amplitude volume, outputting the igneous facies probability for the whole area. The results show good conformity with the input manual interpretation and with well logs, which was not part of the training.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87615682","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183037
D. Hunt
Summary The giant pre-salt Bacalhau field in the Santos basin comprises two distinct Aptian Barra Velha Formation reservoir intervals (BVE200 and BVE100) developed on an isolated lacustrine platform. The reservoirs were deposited onto a complex paleotopography comprising both rifted BVE300 Paraty volcanics and younger volcanic pedestal highs. Bacalhau is a high-pressure field, with a 500 m hydrocarbon column. Hydrocarbons occur in rocks interpreted as being from both shallow water platform top and slope environments. Here we discuss how comprehensive new data from the 2018/2019 appraisal campaign, integrated with existing well data, narrow-azimuth 3D seismic, together with stratigraphic- and seismic-forward modeling provides new insights as to the controls on: 1) rifted and volcanic paleotopography, 2) relative lake-level changes, 3) dominant wind directions, and 4) slope re-deposition on lacustrine carbonate platform, margin, slope development and so reservoir heterogeneity.
位于Santos盆地的巨型盐下Bacalhau油田由两个不同的Aptian Barra Velha组储层(BVE200和BVE100)组成，这些储层位于一个孤立的湖相平台上。储层沉积在一个复杂的古地形上，包括裂谷BVE300斜火山岩和较年轻的火山台地高地。Bacalhau油田为高压油田，油气柱深500 m。岩石中的碳氢化合物被解释为来自浅水平台顶部和斜坡环境。在这里，我们讨论了2018/2019年评价活动的综合新数据，结合现有井数据，窄方位角三维地震，以及地层和地震正演模拟如何为以下方面的控制提供新的见解:1)裂谷和火山古地形，2)相对湖泊水位变化，3)主导风向，4)湖泊碳酸盐岩台地，边缘，斜坡发育和储层非均质性的斜坡再沉积。
{"title":"The Bacalhau Field: New Insights into Lacustrine Carbonate Platform Development, Santos Basin, Brazil","authors":"D. Hunt","doi":"10.3997/2214-4609.202183037","DOIUrl":"https://doi.org/10.3997/2214-4609.202183037","url":null,"abstract":"Summary The giant pre-salt Bacalhau field in the Santos basin comprises two distinct Aptian Barra Velha Formation reservoir intervals (BVE200 and BVE100) developed on an isolated lacustrine platform. The reservoirs were deposited onto a complex paleotopography comprising both rifted BVE300 Paraty volcanics and younger volcanic pedestal highs. Bacalhau is a high-pressure field, with a 500 m hydrocarbon column. Hydrocarbons occur in rocks interpreted as being from both shallow water platform top and slope environments. Here we discuss how comprehensive new data from the 2018/2019 appraisal campaign, integrated with existing well data, narrow-azimuth 3D seismic, together with stratigraphic- and seismic-forward modeling provides new insights as to the controls on: 1) rifted and volcanic paleotopography, 2) relative lake-level changes, 3) dominant wind directions, and 4) slope re-deposition on lacustrine carbonate platform, margin, slope development and so reservoir heterogeneity.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"70 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90941986","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183027
M. Arnemann, V. Abreu, S. Rostirolla, E. Barboza
Summary The discovery of giant hydrocarbon accumulations in the pre-salt play, offshore south-eastern Brazil led to large-scale data acquisition, with dense 2D seismic grid and broad 3D seismic data coverage, with more data being acquired currently. More than 100 exploratory wells had penetrated the pre-salt, with most of the acquired data already in the public domain, including logs, cores, and well reports. This rich geologic dataset is being interpreted in the ATLANTIS Project to build a regional and integrated paleogeographic reconstruction of the Brazilian Southeastern Margin. The goal is to de-risk play-elements presence and quality in the pre-salt section, as well as to build predictive models for CO2 distribution in the region. This project also has the potential to evaluate the remaining potential for economic hydrocarbon accumulations in this important play. Preliminary results indicate that the main, regional controls on accommodation creation and the petroleum systems elements distribution from continental rifting to early drift phases in the region are: inherited Neoproterozoic structural lineaments and Mesozoic continental weaknesses zones, subaerial volcanism pre- and post-continental breakup controlling the development of early seaways and sub-basins, and transcurrent faults zones and consequent transtension and transpression.
{"title":"Tectono-Stratigraphic Evolution of the Brazilian South-Eastern Margin - The ATLANTIS Project and its Impact on Pre-Salt Research","authors":"M. Arnemann, V. Abreu, S. Rostirolla, E. Barboza","doi":"10.3997/2214-4609.202183027","DOIUrl":"https://doi.org/10.3997/2214-4609.202183027","url":null,"abstract":"Summary The discovery of giant hydrocarbon accumulations in the pre-salt play, offshore south-eastern Brazil led to large-scale data acquisition, with dense 2D seismic grid and broad 3D seismic data coverage, with more data being acquired currently. More than 100 exploratory wells had penetrated the pre-salt, with most of the acquired data already in the public domain, including logs, cores, and well reports. This rich geologic dataset is being interpreted in the ATLANTIS Project to build a regional and integrated paleogeographic reconstruction of the Brazilian Southeastern Margin. The goal is to de-risk play-elements presence and quality in the pre-salt section, as well as to build predictive models for CO2 distribution in the region. This project also has the potential to evaluate the remaining potential for economic hydrocarbon accumulations in this important play. Preliminary results indicate that the main, regional controls on accommodation creation and the petroleum systems elements distribution from continental rifting to early drift phases in the region are: inherited Neoproterozoic structural lineaments and Mesozoic continental weaknesses zones, subaerial volcanism pre- and post-continental breakup controlling the development of early seaways and sub-basins, and transcurrent faults zones and consequent transtension and transpression.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"107 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90696370","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183017
N. Zuniga, V. Priimenko
Summary Performing velocity analysis step aiming to estimate velocity of a reflection event, by inverting travel-time curves, demands the extraction of the arrival times of a reflection event in order to obtain its travel-time curve. This extraction is usually performed manually or with techniques which are not automated. For this reason, we propose a technique able to extract travel-time curves of reflection events related to pre-salt structures by reconstructing and comparing their seismic spectra. With our technique, it is possible to find, in a reliable manner, each wavelet and each arrival time of PP and PS reflection events for a pre-salt structure and with OBN data.
{"title":"Automated Travel-Time Picking for Pre-Salt Reflection Events for OBN Data","authors":"N. Zuniga, V. Priimenko","doi":"10.3997/2214-4609.202183017","DOIUrl":"https://doi.org/10.3997/2214-4609.202183017","url":null,"abstract":"Summary Performing velocity analysis step aiming to estimate velocity of a reflection event, by inverting travel-time curves, demands the extraction of the arrival times of a reflection event in order to obtain its travel-time curve. This extraction is usually performed manually or with techniques which are not automated. For this reason, we propose a technique able to extract travel-time curves of reflection events related to pre-salt structures by reconstructing and comparing their seismic spectra. With our technique, it is possible to find, in a reliable manner, each wavelet and each arrival time of PP and PS reflection events for a pre-salt structure and with OBN data.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79688923","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183028
L. Hansen, I. Troth, K. Glitz, E. Nogueira, K. V. Juk, E. Terán, P. R. B. D. Santos, V. Haugse, S. Erlandsen, Ézio M. Silva, E. Schwedersky, Gledsângela Ribeiro Carneiro, Greice Carvalho de Matos, T. D. Oliveira, C. Lima, Dina Regis Recaldes Rodrigues Argeropulos Aquino, C. D. Santos
Summary The giant pre-salt Bacalhau field is located in the Santos Basin, and is the first pre-salt greenfield development by an international oil company (IOC) in Brazil. Bacalhau is a complex, overpressured field with high quality carbonate reservoirs with light oil belonging to the Barra Velha Formation. This work presents the story from the appraisal to development of the production of the field that will be a future cornerstone of Equinor daily production.
{"title":"Bacalhau Project: An Innovative Development Strategy for a Unique Field","authors":"L. Hansen, I. Troth, K. Glitz, E. Nogueira, K. V. Juk, E. Terán, P. R. B. D. Santos, V. Haugse, S. Erlandsen, Ézio M. Silva, E. Schwedersky, Gledsângela Ribeiro Carneiro, Greice Carvalho de Matos, T. D. Oliveira, C. Lima, Dina Regis Recaldes Rodrigues Argeropulos Aquino, C. D. Santos","doi":"10.3997/2214-4609.202183028","DOIUrl":"https://doi.org/10.3997/2214-4609.202183028","url":null,"abstract":"Summary The giant pre-salt Bacalhau field is located in the Santos Basin, and is the first pre-salt greenfield development by an international oil company (IOC) in Brazil. Bacalhau is a complex, overpressured field with high quality carbonate reservoirs with light oil belonging to the Barra Velha Formation. This work presents the story from the appraisal to development of the production of the field that will be a future cornerstone of Equinor daily production.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"110 1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75975226","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}
Pub Date : 2021-09-08DOI: 10.3997/2214-4609.202183041
F. Neves, João Marcos Domingues Dias, C. Ribeiro, P. Coelho, G. Raitz, H. Santos, J. Santos, D. Silva, M. Arena, J. Favoreto, L. Borghi
Summary The Lower Cretaceous Barra Velha (BVE) unit is the main reservoir in our area of study, which consists of heterogeneous carbonates beneath a thick salt layer. Pre-Salt wells have shown that underneath the BVE reservoir, there could be several non-reservoir rocks (e.g., microporous carbonates, shales, volcanics) embedded in different formations that are hard to predict pre-drill. This poses a challenge, as BVE reservoir thickness and quality could be affected by a variety of underlying geological formations with distinct lithologies and facies. The Aptian BVE Formation consists of several hundred meters thick dolomitized limestones and shales. The mud-poor section is the main reservoir interval. The Itapema Fm. consists of thick (hundreds of meters) limestones (including coquinas) and organic rich shales. The Barremian Picarras Fm. is mostly made up of clastic and carbonate rocks, that contain conglomerates, with clasts of basalt and quartz and talc-stevensite shales. Finally, the lowermost and oldest Camboriu Fm. consists mainly of basalts. Despite efforts to understand the main factors driving the BVE reservoir elastic and seismic behavior for 3D and 4D interpretations and reservoir characterization, we still miss advanced geophysical analysis of the interfaces between different geological units that are important for quantitative seismic interpretation.
{"title":"Characterization of Barra Velha Reservoir-Non Reservoir Interfaces in a Pre-Salt Field in Santos Basin-Brazil Using Seismic AVO Modelling.","authors":"F. Neves, João Marcos Domingues Dias, C. Ribeiro, P. Coelho, G. Raitz, H. Santos, J. Santos, D. Silva, M. Arena, J. Favoreto, L. Borghi","doi":"10.3997/2214-4609.202183041","DOIUrl":"https://doi.org/10.3997/2214-4609.202183041","url":null,"abstract":"Summary The Lower Cretaceous Barra Velha (BVE) unit is the main reservoir in our area of study, which consists of heterogeneous carbonates beneath a thick salt layer. Pre-Salt wells have shown that underneath the BVE reservoir, there could be several non-reservoir rocks (e.g., microporous carbonates, shales, volcanics) embedded in different formations that are hard to predict pre-drill. This poses a challenge, as BVE reservoir thickness and quality could be affected by a variety of underlying geological formations with distinct lithologies and facies. The Aptian BVE Formation consists of several hundred meters thick dolomitized limestones and shales. The mud-poor section is the main reservoir interval. The Itapema Fm. consists of thick (hundreds of meters) limestones (including coquinas) and organic rich shales. The Barremian Picarras Fm. is mostly made up of clastic and carbonate rocks, that contain conglomerates, with clasts of basalt and quartz and talc-stevensite shales. Finally, the lowermost and oldest Camboriu Fm. consists mainly of basalts. Despite efforts to understand the main factors driving the BVE reservoir elastic and seismic behavior for 3D and 4D interpretations and reservoir characterization, we still miss advanced geophysical analysis of the interfaces between different geological units that are important for quantitative seismic interpretation.","PeriodicalId":21695,"journal":{"name":"Second EAGE Conference on Pre-Salt Reservoir","volume":"62 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87399812","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：