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11th Simposio Bolivariano - Exploracion Petrolera en las Cuencas Subandinas
- Conference date: 29 Jul 2012 - 01 Aug 2012
- Location: Cartagena, Colombia
- Published: 29 July 2012
41 - 60 of 184 results
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Basement map of the Venezuela Eastern Basin from gravity and magnetic inversion
Authors Nestor Cahuana, Andreína García and Nuris OrihuelaWe present the basement map of the Venezuela Eastern Basin, at 1:500.000 scale, located between the coordinates 61ş to 66ş west longitude, and between 8ş and 11ş north latitude. The gravity anomalies are from Venezuela gravity anomalies database processed from satellite, aerial and marine surveys; whereas the magnetic anomalies are from geopotential combined models. This map was obtained by gravity/magnetic inversion methods: Radial power spectrum, Euler deconvolution, Werner deconvolution; and gravity/magnetic modeling. The depth solutions obtained by applying these techniques, has been associated with the location and depth of sources that cause the anomalies, in this case, with the top of crystalline basement and geological structures involving the basement. Exploration wells data and structurally interpreted seismic sections previously in the area, were used to validate the results. Synthetics anomalies of gravity and magnetism were generated with the aim of comparing the observed with the theoretical response, thus allowing a best fit of the three-dimensional model. The obtained results allow the interpretation of geological structures involving the crystalline basement, as well as proposing new prospective areas.
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Tectonic and subsidence history of the Llanos foreland basin of Colombia
Authors Henry Campos and Paul MannColombia is located in the northwestern corner of South America. The NE-trending Andean mountain range is divided into three separate cordilleras: the Oriental (eastern), Central, and Occidental (western). The uplift of these cordilleras was caused by the combination of east-west shortening due to the subduction of the Nazca and Caribbean plates beneath the South American plate and the collision of the Panama arc-indentor with western Colombia. Between the Guiana Shield and the Cordillera Oriental, the basement dips westward into the subandean Putumayo and Llanos basins, which are separated by the Serrania de la Macarena and the Vaupes arch. The Arauca arch separates the Colombian Llanos basin from the Venezuelan Barinas-Apure basin. The Llanos basin of Colombia covers approximately 194,000 km2 and is considered one of the most prolific hydrocarbon basins along the eastern flank of the Andes in South America (ANH, 2007). The most significant factor affecting the hydrocarbon potential of the Llanos basin was the deposition of marine Cretaceous source rocks that were deeply buried and thermally matured (Moretti et al., 2009), and the multiple phases of orogeny (Parra et al., 2009b, 2010) that produced many structural and stratigraphic traps and pathways for oil migration.
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2nd Edition of the Geological Map of Colombia
Authors Jorge Gómez Tapias and Nohora Emma Montes RamírezThe Geological Map of Colombia-GMC is an ongoing project that started in 2001, the 1st edition was finished in 2007 and now is one of the main functions of the Colombian Geological Survey. The GMC summarizes the superficial geological information of the Colombian territory compiled using ArcGIS 9.3.1 by integration and generalization of 1:100,000 scale geological sheets published by the Colombian Geological Survey. The harmonization was controlled using remote sensing imagery such as Landsat, radar and a 30 m resolution NASA-SRTM DEM. The units represented on the GMC were defined according to a mixed chronostratigraphic-lithostratigraphic classificatory scheme. The technological platform that supports the SIGER is based on the database management systems Oracle 10g and ArcSDE 8.3 for the handling of the data. Additionally, with the objective to feed GMC database, the GIS radiometric ages catalog of Colombia has been made and include with this edition. 2nd edition of the GMC was released in 2012 and includes 70 brand new geological sheets at a scale 1:100,000, actualized official base map of the Geographical Institute Agustin Codazzi-IGAC with MAGNA coordinate system compatible with WGS84 coordinate system, new colors and ages of the International Stratigraphic Chart 2008, the Tectonic framework of NW South America and the Caribbean with 2011GPS vectors 2011 and the geological harmonization with the geological maps of Peru and Brazil after two workshops in 2009 and 2011 with colleagues of the CPRM and INGEMMET.
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Modelo evolutivo de estratigrafia de secuencias en el cono de rio grande (offshore brasil).
Authors Maria Bejerano and Luis CastilloEl Cono de Rio Grande se encuentra ubicado en la Cuenca de Pelotas en el Offshore de Brasil. Esta geoforma se caracteriza por encontrarse en una margen tectónica pasiva que continúa hasta el presente. A causa de esta extensión, el mar progresivamente ha invadido zonas continentales y su nivel base ha tenido fluctuaciones a través del tiempo. El presente trabajo es un estudio integrado de la sismoestratigrafía con la estratigrafía de secuencias. Así se tienen herramientas modernas en el campo de la geología estratigráfica, donde la interacción entre el espacio de acomodación y la sedimentación juegan un papel fundamental para la determinación de unidades genéticas, en este caso, con la sismoestratigrafía. En las secciones sísmicas fueron hechas las interpretaciones basadas en estratigrafía de secuencias, donde se determinaron cuatro secuencias estratigráficas limitadas por discordancias. En cada una de las secuencias se establecieron los diferentes tratos de sistemas y superficies, definiendo paquetes de tercer orden. Una vez realizada la interpretación, se construyó un modelo evolutivo estratigráfico del Cono de Río Grande teniendo en cuenta parámetros tales como subsidencia, cambios del nivel eustático y aporte sedimentario.
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Basement setting in the east edge of the parnaíba basin, using air gravimetric, magnetometric, seismic and land gravity data
Authors José Bezerra, André Rugenski, Renato Silveira and Roberto AguiarThis paper presents a joint interpretation of aerial survey data from gravimetry and magnetometry, 2D seismic data and terrestrial gravity data in order to examine the stratigraphic framework and configuration of the basement in the central-eastern Parnaíba Basin in region of Transbrasiliano Lineament north-northeast of Brazil. The main objective of this study is to map the architecture and composition of the basement, the structural, stratigraphic and volcanic rocks, in order to characterize the hydrocarbon prospectivity. The Transbrasiliano Lineament (LTB) is a suture zone of NNE-SSW direction, which reaches 100 km wide, featuring behind the geophysical constrain Parnaíba Basin resulting on zones of crustal weakness reactivated since the Precambrian. The tectonic movement in LTB reflects the evolution of Paleozoic and Mesozoic sedimentary basins along its length. Fairhead et al., 2007, based on aeromagnetic data from Brazil and Northern Africa, considers the LTB as part of the crustal lineament Argentina - Brazil - Algeria (ABA). The workflow includes integrated interpretation of 2D seismic, gravity data and detailed land-scale aerial survey data covering gravimetric and magnetometric methods with imaging and filtering; solutions depth of magnetic basement using Werner deconvolution, Euler technique and half slope of Peters; 2D seismic time and sections depth in the initial links with gravity and magnetic modeling.
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An Integrated View of Textural Variations in the Eagle Ford, South Texas, USA, as seen in Core, CT Scans, Thin Section and SEM
Authors Brian Driskill, Andrew Govert and Lori HathonUnconventional reservoirs are becoming an important source of hydrocarbons around the world. For many years, detailed studies of mudrocks were not conducted largely due to the pervasive view that muds, being the result of fine-grained settling within a quiet water column, were ‘uneventful’. Recent research, however, indicates that mudrocks are internally more complex than previously thought and mostly likely deposited under dynamic conditions. Recognition of the complexity of mudrocks has led to a desire to more fully describe finegrained cores with attention to textural variations. From an exploitation point of view, understanding the fine-scale structure of mudstones is a key part to building a framework with which to better predict reservoir vertical and lateral variability. The Cenomanian-Turonian Cretaceous Eagle Ford Formation of the Texas Gulf Coast is a dark grey marl that functions as both source and reservoir. From multiple cores within both the oil and gas-condensate windows, a database of core descriptions, thin sections, high-resolution helical computed tomography (CT) scans, and SEM images of ion-milled surfaces was built. Observations from these data were used to create an interpretation of the Eagle Ford’s texture and fabric. In particular, the CT data was fund to be very helpful for understanding the internal fabric and was used to initially break the rock into fabric units. An outcome of this work was an understanding of why a ‘universal’ electrofacies model was elusive. Tying these observations to larger scale cycles seen in well logs and outcrops created a predictive model for reservoir quality.
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How to compute the gas in place on unconventional gas shale play
More LessThe conventional prospect charge is almost always evaluated thanks to basin model. They allow the explorationist to compute subsidence history, source rock maturation and fluid migration and accumulation versus time. At the beginning of the gas shale exploration success story, dynamic trial and error approaches have been common, apparently without too much of geological input in the decision. However, careful basin analysis may help to predict where the source rocks have the adequate mineralogy to be frac and the adequate TOC and richness to generate gas. The temperature, pressure and TOC versus time could be modeled and therefore the adsorbed volume of gas that have to be added to the free one in the porosity.
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Exploración de Plays No Convencionales para Gas en la Formación Porquero de la Cuenca del Valle Inferior del Magdalena, Colombia
Authors Ivan Leyva, Juan Arminio, Rudyard Vega, Jairo Lugo and Angel DasilvaLa cuenca del Valle Inferior del Magdalena en Colombia se ha caracterizado por su tendencia a producir gas y condensado. En la subcuenca de Plato, empleando sísmica 3D y análisis de atributos AVO e inversión elástica y acústica, se definió un play exploratorio en el flanco de un diapiro incipiente de arcilla. A partir de esta información se estableció la prospectividad para gas en una espesa sección de lutitas masivas de la Formación Porquero del Mioceno Medio, la cual fue confirmada con la perforación de dos pozos exploratorios.
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Análisis multi-atributos para la caracterización sísmica de prospectos para gas en la Cuenca del Valle Inferior del Magdalena, Colombia
Authors William Marin, Milagrosa Aldana and Jesús SierraEl presente trabajo tiene como principal objetivo el cálculo, comparación, análisis e integración de diferentes técnicas de atributos sísmicos con información geológica y petrofísica, para la disminución de la incertidumbre en la caracterización de un yacimiento e identificación de zonas prospectivas para gas en la Cuenca del Valle Inferior del Magdalena en Colombia. Previo al análisis de atributos, se realizaron análisis de física de rocas y modelado AVO utilizando registros de pozos perforados en la zona de estudio. Como resultado de este análisis se obtuvo que la impedancia acústica de las arenas reservorio tiende a ser muy similar a la de las lutitas; sin embargo, cuando estas arenas están saturadas de gas, la impedancia disminuye ligeramente respecto a las arenas con agua y lutitas circundantes. A partir del modelado AVO se confirmó que las arenas gasíferas del área son del tipo clase II sin cambio de polaridad en la amplitud. Descomposición espectral, inversión acústica e inversión simultánea fueron los principales atributos aplicados. Los atributos calculados en el dominio pre-apilamiento (Impedancia P, Impedancia S y densidad) lograron una mejor definición de arenas gasíferas que los atributos calculados en el dominio post-apilamiento. A pesar de ello, los resultados de la aplicación de descomposición espectral e inversión acústica post – apilamiento constituyeron buenos indicadores directos de hidrocarburos, resaltándose la importancia de estos atributos cuando se carece de datos pre-apilado.
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Nuevo enfoque estructural en la Cuenca de Huallaga, y su implicación en la Exploración de Hidrocarburos
Authors Rubén Pérerz-Martin and Gonzalo Zamora-ValcarceLa cuenca de Huallaga se encuentra situada en la zona de antepaís del subandino peruano. Es una cuenca poco explorada históricamente debido a las dificultades geográficas que presenta y a que el único pozo Ponasillo 1X, perforado en 1992, resultó fallido. Esta cuenca se aracteriza por una serie de anticlinales elongados NW-SE separados por sinclinales con una importante secuencia terciaria. Interpretaciones previas clásicas relacionan estas estructuras con la existencia de un sistema diapírico a partir de depósitos evaporíticos de edad jurásica o anterior. Avances en el conocimiento del comportamiento de tectónica salina en zonas compresivas, junto con modelos desarrollados en otras provincias del subandino han permitido la creación de un nuevo modelo estructural para la zona. Mediante el uso de datos sísmicos disponibles y geología de superficie se ha desarrollado un nuevo modelo estructural con un espesor de evaporitas menor que el propuesto clásicamente. La formación de las estructuras estaría relacionada a pliegues de despegue y estructuras tipo dúplex, favorecidos por la presencia de estas evaporitas. En base a este modelo y mediante el análisis de las relaciones geométricas, se han estimado acortamientos y profundidades del nivel de despegue. Este modelo estructural, más acorde con lo que se observa tanto en superficie como en la información de subsuelo, abre un nuevo horizonte exploratorio en una cuenca de frontera.
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Campos Apiay y Suria, treinta ańos después: Una perspectiva geológica
More LessLos Campos Apiay y Suria descubiertos por Ecopetrol se localizan en el sector del “Foreland” de la Cuenca Llanos de Colombia, a la fecha han producido 250 MM barriles de petróleo de diferentes calidades y de tres unidades estratigráficas. Desde su descubrimiento ha cambiado progresivamente la visión geológica con un impacto directo en el incremento de reservas y producción así como en la visualización de nuevas áreas prospectivas, gracias al trabajo en equipo y a la continua aplicación de tecnologías de última generación. Su desarrollo se agrupa en tres etapas: la primera abarca los diez primeros años donde se perforan pozos de evaluación, delimitación y de desarrollo basados en información sísmica 2D y en un modelo geológico estructural de extensión y compresión, focalizados principalmente en el desarrollo de la unidad K2. Una segunda etapa inicia con la adquisición de sísmica 3D, que después de su interpretación cambia sustancialmente el modelo estructural a uno compresivo con componente de rumbo y permite la perforación de nuevos pozos en locaciones óptimas, maximizando su productividad aquí se incluye el primer pozo horizontal, adicionalmente se visualizan nuevas áreas adyacentes, en esta etapa se continua focalizando en el K2 y visualiza la potencialidad de la unidad K1. En la tercera etapa se hace reprocesamiento sísmico, reinterpretación estructural y estratigráfica, modelos de inversión sísmica y de atributos sísmicos lo que permite una agresiva campaña de perforación “infill” con pozos altamente desviados y horizontales, se desarrollan conjuntamente las unidades K2, K1 y T2. Actualmente se continúa reinterpretando y planteando nuevas ideas.
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Current practises in design of 3d land seismic programs or: “3d” stands for design for density and diversity
More LessBy the early ‘90s we were focused on how to produce a good and stable stacked section, then we would post-stack migrate our volumes. Spatial resolution was related to bin size. Designs were driven by considerations of desired fold (determining line spacings) and post-migration resolution (determining bin size). Design philosophy could be summarized as: “design parameters that will produce a good stacked data volume, and account for the fact that post-stack migration will steepen dips and require smaller stacked trace intervals, therefore smaller bins”. With Pre-stack time migration we realized that fold and bin-size were not the most important driving factors. Producing a data set that provides good sampling of migration operators in all domains will allow the migration process to output data of maximum resolution. Output trace spacing is not limited to bin size. Design philosophy shifted from a focus on fold and bin-size to a focus on trace density and statistical diversity (in offsets, azimuths and midpoints). In other words: “design parameters that deliver what is needed by a pre-stack migration operator and then let the migration produce the image we need”. Now based on 5-component COV matrix completion data reconstruction, we can restate our objective as: “design parameters that deliver what is needed for robust interpolation, then the interpolator will provide the traces needed by a pre-stack migration operator and then the migration will produce the image we need”.
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“Santonian Channelized Systems of The Santos Basin, Brazil: New Discoveries and Perspectives”
The Santos Basin is located in the Southeast region of Brazilian continental margin. It encompasses around 350,000 km2 of area, limited to the North with The Campos Basin by the Cabo Frio High and to the South with The Pelotas Basin by the Florianópolis Platform (Figure 1). In the same year of its creation OGX acquired four (4) exploration blocks in the 9th Bid Round organized by the National Petroleum Agency (ANP). Located in the Santos Basin these four blocks are situated in water depths of 150 meters and at 90 km from the coast of the states of Săo Paulo and Rio de Janeiro. The Santos Basin Petroleum Systems are well known and very active as confirmed by many recent discoveries made from 2002 on. Two important intervals of source rocks are present in the basin, (a) the Barremian (~128 My) lacustrine shales and (b) the Albian-Cenomanian (~99 My) marine shales. These source rocks generated the oil and natural gas discovered in reservoirs of many types and ages: (a) Eocene Sandstones in the northern part of the basin, (b) Santonian and Campanian Sandstones in the central part, (c) Oligocene and Albian-Cenomanian Sandstones and Albian Oolitic Calcarenites in the southern part and, (d) most recently, the Aptian Microbiolite Carbonates in the Pre-Salt area. Additionally, OGX found in its shallow water blocks Albian fractured Carbonates. The present work focuses on the discoveries that OGX has made in sandstones belongs to Santonian channelized systems. It will show the stratigraphic framework of these Santonian reservoirs and to try understanding the evolution of these systems in terms of sequence stratigraphy. Finally, it will present the OGX plans to delimit and to development this area, considering the potential of production, which was confirmed by two formation tests in different discoveries, Natal and Maceió prospects. These discoveries are the result of an aggressive investment plan and innovative exploratory vision of OGX.
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Robust prediction of pay sands in clastic reservoirs with seismic inversion attributes, Campos basin, Brazil
Authors Heidy Correa-Correa, Gunnar Holmes and Joshua WoodworthThe Eocene deepwater sandstones are the main target in several fields in the Campos basin in Brazil. These sandstones are considered typical unconsolidated to partially consolidated clastic reservoirs, with porosity values in the range of 26-28%. Recent publications have shown the effectiveness of AI-SI attribute derived from seismic inversion to highlight zones of interest in clastic reservoirs, particularly in Brazil.
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Intermontane basins and hydrocarbon potential at the Central to Northern Andes
Authors Wilver Hermoza, Roger baudino and Maria Baca-AlvarezIn the Central to Northern Andes transition zone (Ecuador and Northern Peru), several Tertiary intermontane basins have been preserved (e.g. Bagua Basin in Peru, Zumba, Nabon, Loja, Malacatos- Vilcabamba, Giron and Cuenca basins in Ecuador). The analysis of these intermontane basins showed similarities in their sedimentological evolution and ages of infilling; however structurally, three groups can be separated: the Cuenca and Giron-Santa Isabel basins related to dextral movement of allochtonous terranes sutures (Raspas- Peltetec; Calacali-Pallatanga-Palenque). The Loja and Vilcabamba-Malacatos basins are associated to N-S sutures activation (Las Aradas- Zamora). The third group includes the Bagua Basin and others small piggyback basins purely related to the eastward migration of the main fold and thrust deformation front of the Central Andes during the Upper Miocene. Exploration point of view, the Miocene intermontane basins often contain a thick sequence of lacustrine and/or shallow marine deposits that could host potential source rocks. Indeed, coal layers are described and were traditionally exploited for domestic use. Nevertheless, the Miocene basin fill could at depth have triggered the activation of Mesozoic and older petroleum systems. In the area of the Bagua Basin exists two potential petroleum systems. The Jurassic (Aramachay Fm) and Cretaceous (Goyllarisquizga Gp and Inca Fm) sequences have an excellent source rock potential. One oil seep sample hosted in the Upper Cretaceous reservoirs was collected in the Bagua Basin. According to its geochemical characterization it is from a marine source rock, kerogene type II and a Pre-Cretaceous age has been postulated.
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“Parnaíba Basin – The Awakening of a Giant”
The Parnaíba Basin is located in a considered exploratory frontier area, in the Brazilian Northeastern Region. The basin has about 600.000km² with a sedimentary section reaching approximately 3.500m thickness in its depocenter (Fig. 1). The Parnaíba Basin returned to the oil exploratory scenery after two decades without activities, with the discovery of two gas fields, two other accumulations in delimitation stage and significant hydrocarbons shows in recent drilled wells. The Gavião Real and Gavião Azul fields are now under production development phase, and the Bom Jesus and Fazenda Torrão accumulations are being evaluated by field delimitation phase. These discoveries are the result of an aggressive investment plan and innovative exploratory vision of OGX Petróleo e Gás S. A., acting with MPX Energia S. A. and Petra Energia S. A. in seven blocks and with MPX Energia S. A. and Imetame-Delp-Orteng Consortium in one block, as partnerships, breaking old paradigms toward Paleozoic basins. Using 2D and 3D seismic data, acquired in record time, and incorporating new ideas and alternative geological models has resulted in great success to the basin so far. The great number of mapped leads to be drilled in the future, based in the updated seismic interpretation, points out an expressive hydrocarbon potential in the Parnaíba Basin increasing OGX’s portfolio by far.
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An investigation of the provenance and post-depositional thermal history of the Cenozoic Amagá Formation from the transition between the Cordillera Central and Oriental, Colombia
Authors Ian Duddy, Pedro Parra Mantilla, Vicente Rodriguez and Paul GreenThe Oligo-Mioceno Amagá Formation comprises at least 1500 m of non-marine quartzose and lithic sandstones, carbonaceous shale and coals preserved in a roughly linear basin along the Cauca Valley, west of the Romeral fault system in the transition between the Western and Central Cordillera of Colombia. We have used AFTA® apatite fission track analysis and ZFTA zircon fission track analysis to provide unique constraints of the provenance and post-depositional the thermal and burial histories of a suite of Amagá Formation sandstones from the vicinity of Santa Fe de Antioquia (near Medellin). Independent constraints on the maximum temperatures experienced by associated coal seams have been determined from vitrinite reflectance data. These results have important implications for the source of the Amagá Formation sediments and the tectonic evolution of the adjacent Altiplano Antioqueño of the Central Cordillera, where AFTA data show clear evidence of kilometre-scale denudation during the Late Eocene to Early Miocene (40 to 20 Ma) and since the late Early Miocene (18 to 0 Ma), overlapping with the deposition of the Amagá Formation. The ability of AFTA to provide direct constraints on the time at which both sedimentary and “basement” sequences were uplifted and eroded in tectonically complex regions provides a powerful tool for understanding the tectonic evolution of Colombia during the Cenozoic.
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Presencia de Gilsonita y bitumen en la cuenca Valle Medio del Magdalena: “Un reto para la perforación exploratoria”
Authors R. Acevedo, D. Daza, M. Prince, D. Rojas and C. SanchezLa “Gilsonita” o bitumen es un hidrocarburo sólido del grupo de las asfaltitas que en el sector norte de la cuenca Valle Medio del Magdalena –VMM-, se ha presentado tanto en afloramientos de rocas sedimentarias como en subsuelo (relacionada ya sea a la posible roca fuente o a secuencias siliclásticas posteriores), y aprovechando zonas de fallas. En otroas partes es conocida como Uintaita, asfaltita ó asfalto natural. Es brillante, de color negro, fractura concoidea, en apariencia muy similar a la del mineral Obsidiana. Durante la última campaña de perforación llevada a cabo por Petronorte S.A. entre 2009 y 2010 en la cuenca VMM, se detectó presencia de Gilsonita en dos pozos, en los dos casos ocasionó serios problemas durante la perforación tales como pérdidas de lodo y empaquetamiento, ya que la aparición de este mineral en el subsuelo presenta complicaciones desde el punto de vista mecánico a profundidades mayores a 6500 pies. La información de ocurrencia de Gilsonita durante perforación de pozos es escasa al igual que la documentación de estudios geológicos relacionados con su génesis en cuencas colombianas. Dar a conocer los resultados de perforación y de análisis de muestras permite abrir una discusión técnica tanto para las actividades de exploración como de perforación (análisis de muestras de pozo y afloramiento, métodos de disolución, identificación con atributos sísmicos, procesos de generación – migración de hidrocarburos, etc) con el fin de conocer la experiencia de este tipo de ocurrencias en subsuelo. Este trabajo describe de forma general las tres diferentes ocurrencias de Gilsonita en la cuenca VMM en Colombia con el fin dar a conocer sus actividades de perforación asociadas y aportando al entendimiento de su geología.
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ESTIMACIÓN DE RIESGO EXPLORATORIO APLICANDO TECNICAS DE TOMA DE DECISIÓN BAJO INCERTIDUMBRE
Authors Rober Yibirin and Juan ArminioEn los últimos treinta años, la industria de exploración de hidrocarburos ha incorporado técnicas probabilísticas y de toma de decisiones bajo incertidumbre para estimar el valor relativo de activos exploratorios, sean estos plays, pista (“leads”) ó prospectos. En este trabajo presentamos un análisis crítico del cálculo del Riesgo Exploratorio tal como se aplica en la actualidad y proponemos el uso consistente y sistemático de las técnicas de toma de decisiones bajo incertidumbre para estimar la probabilidad de éxito al evaluar prospectos exploratorios. En tal sentido proponemos una aproximación alterna al método multiplicativo que involucra probabilidad de éxito de factores individuales del sistema petrolero actualmente en uso. Esta opción permite incorporar al cálculo un mayor número de variables del sistema petrolero, admitiendo una posible interdependencia entre ellas.
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Mejoramiento de la Imagen Sísmica y su Aplicación en la Definición de Sistemas Turbidíticos Asociados al Abanico del Magdalena
Authors Claudia Duenas, Sonia Ospina, Sergio Ibańez and Jaime MartinezEn la última década se ha realizado adquisición sísmica marina 2D y 3D en la costa Caribe Colombiana, en el Abanico del Magdalena. La identificación de trampas con importante componente estratigráfico ha planteado retos en términos de imagen sismica, contenido de frecuencia y en algunos casos preservación de amplitudes en las áreas de interés. La absorción de energía en capas de carbonatos, los múltiplos asociados al fondo marino, la baja relación señal/ruido, las bajas frecuencias y la presencia del BSR (“Bottom simulating reflector”), se han identificado como las causas principales del deterioro de la imagen sísmica. Con el fin de mejorar la calidad de los datos y reducir los problemas mencionados, se realizaron procesamientos que incluyen migraciones preapilado en tiempo y en profundidad usando algoritmos como Kirchhoff, WEM (“Wave equation migration”), CBM (“Control Beam Migration”); incluyendo anisotropía VTI (“Vertical Transverse Isotropy”) en algunos casos. Los resultados muestran imágenes sísmicas con mejor relación señal/ruido y aumento del contenido de frecuencias en algunos casos, lo cual reduce la incertidumbre en la definición de prospectos y estimación de recursos.
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