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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
1 - 20 of 184 results
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Seismology information: impact on drilling and production activity. Casabe and satellite fields. Middle Magdalena River Basin (MMVB).
Authors Juan Peralta-Vargas, Oscar Bravo, Liliana Martinez, Andreas Suter and Cesar LealSeismology information is used by Earth Sciences professionals dedicated to earthquake analysis and structural geology for Neo-tectonic application. Oil business normally, did not pay too much attention to this information because drilling activity never exceed 7,5 Km investigation. However, active basins or field located in foothills are vulnerable for earthquake and risk should be evaluated.
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Lithology and fluid estimation in 3D based on seismic inversion and geostatistics: the Rubiales field case
Seismic data and well-logs are the major sources of information for lithology discrimination and determination of the spatial distribution of reservoir sands and fluids. In Rubiales and other Llanos fields, conditions are adequate for accurate mapping of lithology based on elastic inversion of seismic data and petrophysical estimation of shale volume fraction. In general, sandstones are more rigid and lighter than shale at the basal Carbonera formation that comprises the reservoir. Spatial distribution of sands derived from seismic information is shown to be heterogeneous with layers and lenses of varying reservoir quality and communication across stratigraphic levels. The description obtained from the elastic inversion corresponds very well with the acquired well-log information and the geostatistical characterization of shale fraction derived from well-logs. This morphological complexity accentuates the importance of the 3D estimation of lithology and fluid saturation in the area. Seismic sensitivity to fluid saturation in the Rubiales field is smaller than lithology sensitivity, due to the density similarities between the heavy oil and brine. However, the spatial information provided by the large number of wells in the field, combined with the seismic information on lithology (which conditions the oil accumulation) provides an effective mapping for oil-bearing sands in 3D. We achieve an adequate combination of this information by geostatistical means, conditioning the estimation of reservoir properties to well data and seismically derived shale fraction. The study has been relevant for the interpretation of the complex sand morphology, water-oil contacts, the location of horizontal wells that increase the productivity of the field and the definition of the static model for the area.
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Caracterización estratigráfica, geoquímica y estructural de la Formación los Cuervos como roca generadora de hidrocarburos, en la parte sur de la Cuenca del Catatumbo
Authors R. Aguilar, A. Rangel, J.R. Delgado, C. Mora and P. ParraEn la Cuenca del Catatumbo sobre el flanco noreste de la cordillera oriental aflora la Formación Los Cuervos, la cual dentro de su disposición estratigráfica alberga secuencias de rocas con altos contenidos de materia orgánica. Estratigráficamente hablando en la formación se pueden identificar tres miembros, a saber, un miembro superior caracterizado por intercalaciones de lodolitas, arcillolitas y areniscas (arcosas), un miembro intermedio caracterizado por intercalaciones de lodolitas algunas lutitas y mantos de carbón, y un miembro inferior caracterizado por lodolitas, arcillolitas, lutitas y algunas intercalaciones de mantos de carbón. El modelo estructural de la zona corresponde a ambientes compresivos con fallamientos inversos y plegamientos que dan lugar a estructuras alineadas concordantes con la dirección preferencial de los esfuerzos, por lo que es común encontrar bloques alineados en dirección Norte Sur y variantes de las mismas (NW-SE, NE-SW). El potencial en cuanto a generación de hidrocarburos evaluados a partir de la petrografía orgánica y la pirolisis Rock-Eval indica buenos contenidos de materia orgánica principalmente tipo II en ventana de generación de crudo y gas. Los procesos de sedimentación están asociados a ambientes deltaicos, con alguna influencia de corrientes fluviales, con subambientes de llanuras de inundación y llanuras marginales con espesores variables que pueden alcanzar 200m a lo largo de la sección.
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Cenozoic Petroleum Systems of the Sinú – San Jacinto Basin. Exploratory Perspectives of a Promising Frontier
Authors Roberto Aguilera, Jorge Cortes and Jaime NińoThe Sinú San Jacinto Basin (SSJ) although the abundance of oil and gas seeps, is an under-explored and poorly understood basin, especially on the dynamics of the petroleum systems. A long lasting exploratory paradigm about the basin is the absence of source rocks for liquid hydrocarbons in the Cenozoic sequence and that the oil found in wells and seeps has provenance from upper Cretaceous rocks (Cansona Fm.). However, recent studies of source rock quality show that in the Cenozoic sedimentary succession, particularly of Paleocene age, there are intervals with source rock characteristics appropriate for generation of liquid hydrocarbons, which is corroborated by detailed studies of biomarkers from rock extracts, crude oils and seeps in the basin, suggesting that the input of hydrocarbons sourced from units deposited during the Cenozoic is more important than previously believed for the basin, being probably the most important source. Similarly generation models of some depocenters, calibrated with thermal maturity data (Tmax and% Ro) and biomarkers, indicate that the Cenozoic sequence, especially Paleogene rocks, can reach maturity conditions suitable for hydrocarbons generation similar to those estimated from biomarkers from crude oils in the basin. These results open a new spectrum of exploration opportunities in conventional and unconventional petroleum systems associated with the Cenozoic, increasing the prospectivity potential of this under-explored basin.
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Estratigrafia entre el turoniano y el paleoceno superior sobre las cuencas cesar, cordillera oriental, valle medio del magdalena, y llanos norte, colombia
More LessEl análisis estratigráfico para el intervalo Turoniano - Paleoceno, en las cuencas del Cesar, Cordillera Oriental, Valle Medio del Magdalena y llanos Norte, indica que este periodo de tiempo fue dominado por dos periodos de acenso en el nivel del mar, uno en el Turoniano Inferior y otro en el Campaniano Superior. El primer ascenso coincide con un evento máximo global, pero su continuidad lateral indica que podría estar controlado por tectónica, como lo seńalan (Cooper et al., 1995; L. Sarmiento, 2001). La superficie del Campaniano superior y los patrones tanto retrogradacionales como progradacionales hasta este periodo de tiempo, posiblemente se relacionen con subsidencia térmica normal. El Miembro Socuy de la Formación Colon en la Cuenca del Cesar, podría representar una sección condensada del Coniaciano Tardío al Campaniano y/o una superficie de discontinuidad en donde la totalidad o parte de dicho intervalo de tiempo este ausente. Durante el Maastrichtiano Tardío al Paleoceno Temprano, la sedimentación de todas las Cuencas fue controlada por procesos de subsidencia fuertes, que han sido atribuidos a procesos de carga flexural producto de la deformación de la orogenia Andina (Cooper et al., 1990; L. Sarmiento 2001). El proceso de subsidencia tectónica ha sido diferente en tiempo y en intensidad en las diferentes cuencas, sin embargo son muy pocos los sitios en donde se dispone de datos biocronológicos (e.g Bayona et al., 2004) que permitan comparar los procesos que afectan el registro estratigráfico en márgenes activas. (Molinares, 2006) sin publicar.
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Cuantificación de Recursos Hidrocarburíferos Prospectivos en un Sector de una Cuenca Frontera - Aplicación: Cuenca Frontera Colombiana
Authors Helena Ribón, Nicolas Santos, Aristóbulo Bejerano and Sait KhuramaEl aumento en la demanda mundial de hidrocarburos, la declinación de los campos maduros y los altos precios del petróleo están impulsando una nueva fase en la exploración de recursos hidrocarburíferos en cuencas frontera. En estas áreas hay escasez de información y la geología de la cuenca aún no se comprende totalmente, por lo que los riesgos de prospección y exploración son difíciles de evaluar. En Colombia, vastas áreas del territorio catalogadas como cuencas frontera siguen siendo inexploradas y ofrecen el potencial para el descubrimiento de importantes acumulaciones de hidrocarburos que permitan mantener la seguridad energética del país; lo cual sugiere la necesidad de desarrollar una metodología de integración y modelamiento que permita el mejoramiento innovador de la atractividad de las cuencas frontera colombianas y así darle un valor agregado a la información y conocimiento que actualmente se tiene de las mismas. Este estudio tiene como objetivo plantear una metodología para el análisis interpretativo y multidisciplinario de prospectos, con el fin de describir su naturaleza, geometría y disposición; cualificar y cuantificar propiedades de roca y fluidos, y establecer distribución y volúmenes recuperables de hidrocarburos mediante la integración de aspectos estructurales, estratigráficos, sedimentológicos, petrofísicos y de fluidos, en un modelo único que permita determinar de una manera preliminar los posibles recursos hidrocarburíferos presentes en un sector de una cuenca frontera, mediante simulación probabilística.
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Seismic Stratigraphic Analysis on the Off Shore (Pelotas Basin)
More LessAs a strategy of exploration of divergent margins through deep and ultra deep water, the understanding of this challenging and poorly known environment is really relevant in terms of understanding the evolution of the basin. Recent advances in technology, in marine seismic acquisition, processing, and interpretation, has become increasingly important the continental – oceanic boundary for petroleum system within a basin still unexplored for hydrocarbons. Due to recent discoveries in the succession pre salt and post salt in the Santos and Campos Basin, is worthwhile to know what is the structural and stratigraphical context of the southernmost basin of the Brazilian margin, The Pelotas Basin. The aim of this paper is to analyze this thick stratigraphic succession using sequence stratigraphy, seismic attributes in order to create and contribute a better understanding of this basin (Pelotas) and its Africans analogues, the Walvis and Nambia basins.
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Origin and Kinematics of Extension in the Llanos Basin, Colombia
Authors Gabriel Veloza-Fajardo and Guillermo Hernandez-Ladinos. However the origin and kinematics of these faults have received little attention. Our preliminary analysis indicates that these faults are related to brittle deformation of the lithosphere, as a response of a rapid onset of tectonic loads in the growing Eastern Cordillera during Late Miocene to recent times. The magnitude of extension decreases eastward, as the distance from the thrusting front increase, ranging from hundreds of feet in the Upia area to tenths of feet in the Sabanero – Rubiales area. Timing of fault initiation and activity are constrained based on recent thermochronological data from the Eastern Cordillera, that shows an abrupt increase in shortening, from 1.5 – 1.8 mm/yr during the Upper Miocene (~2 Ma ago) to 3.5 – 5.0 mm/yr for the Plio-Pleistocene (2 Ma ago), and also from regional correlations with published biostraigraphic data of the basin. The deformation style of the northern portion of the Llanos basin is compared with the foreland basins of Putumayo (Colombia) and Oriente (Ecuador), where the trapping mechanism, rheology of the crust and basin fill are strikingly different, leading us to conclude that these basins represents two different tectonic provinces, that are being sutured by the north-eastern extension of the Algeciras - Guayaquil fault system, that extends into the Llanos basin transferring slip from the trench inboard.
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Giant Mass Transport Complex from the Distal Magdalena Fan, Offshore Colombia : Seismic Characterization
Authors Stephen Leslie, Juan Carlos Mosquera, Ingrid Cordon and Oscar Lopez-GamundiA giant (>3000 km3) mass transport complex (MTC) is imaged from the distal Magdalena Fan, offshore Colombia. The MTC is imaged on a loose grid of 2D seismic data, located in ultra-deep water 150-200 km north of the city of Barranquilla. The deposit varies in thickness from ~40-200 m, thinning onto pre-existing seafloor topography. The area of the slide is >25,000 km2. Calculations indicate a volume larger than 3000 cubic kilometers of sediment was involved in this single catastrophic event. The MTC is likely Pleistocene in age as constrained by the DSDP site 153 well penetration. The top of the deposit is defined by a relatively rugose seismic reflector and lies only 150 m below the present day seafloor. Internally, a variety of seismic facies are present, ranging from incoherent/chaotic within the core of the deposit, to continuous reflections broken by small scale, regular reverse faults at the margins. Little to no erosion appears to have occurred at the base of the deposit, as evidenced by continuous and conformable reflections in the interface between the underlying sediments and the base of the MTC.
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Pleistocene to Recent Channel / Levee System from the Slope of the Magdalena Fan
Authors Stephen Leslie, Ingrid Cordon and Oscar Lopez-GamundiThe Pleistocene to Recent Magdalena Fan, offshore NW Colombia provides excellent examples of mid to upper slope submarine channels and associated levee complexes. We focus on a single channel levee complex which we identify as the Manga Channel Levee Complex (MCLC). The internal architecture of the MCLC is clearly defined by high quality 3D seismic data recently collected in the area. Four distinct seismic facies are visible, 1) relatively discontinuous groups of chaotic reflections of variable amplitude, 2) thick packages of low amplitude, continuous and converging reflectors, 3) groups of high amplitude, stacked reflectors and, 4) Laterally continuous packages of low to medium strength reflections that drape underlying topography. We interpret these facies to represent chaotic mass transport complexes, levee and overbank silts and shales, channelized conglomerates/sands, and a hemi-pelagic blanket of silts and shales respectively. Processes such as channel establishment, evolution, and abandonment are identified in the dataset.
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Caracterización de las Electrofacies del Grupo Cogollo, Cuenca de Maracaibo, Occidente de Venezuela
Authors Iván Baritto and Jorge ReverónEl Grupo Cogollo es el principal yacimiento carbonático Cretácico en la Cuenca de Maracaibo en el Occidente de Venezuela y está conformado por las formaciones Apón, Lisure y Maraca. La zona de este estudio está localizada en el Campo Urdaneta y en el Campo Bloque VIII. El objetivo principal de este estudio fue el análisis de las electrofacies del Grupo Cogollo en el pozo de referencia VLB-704, ubicado en el Bloque VIII, a través de la utilización de sus principales registros eléctricos, la información sedimentológica detallada de núcleo y la extrapolación posterior de las electrofacies a los otros pozos localizados en el Campo Urdaneta (UD-791, UD-103, UD-117, UD-132 y UD-139), donde no hay disponible información de núcleos o facies sedimentarias, usando para esto el software EasyTrace.
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Chemostratigraphic correlation of cretaceous cansona formation outcrops and implications on the interpretation of its depositional environment
Authors Leonardo Mogollón, Luz Stella Vargas, Jael Pacheco, Geovanni Romero and Victor RamirezIn the southern Colombian Caribbean coast (Sinú-San Jacinto Basins) a significant potential for hydrocarbon generation has been identified. This potential is also confirmed by the occurrences of oil and gas seepage on the surface. Previous research has suggested these manifestations, both liquid and gaseous to be correlated with source rocks of Cretaceous and Tertiary age. The absence of oil-rock correlations, the immaturity and the type of kerogen from the Tertiary rocks proposed as potential source rocks, have redirected the attention to the detailed study of the Cretaceous Cansona Formation. 460 rock samples collected from outcrops of the Cansona Formation in six different localities were characterized using basic geochemical techniques (Total organic carbon (TOC), RockEval pyrolysis VI) , Mass spectrometry with inductively coupled plasma (ICP-MS, macro elements and trace elements) and total sulfur (LECO sulfur analyzer carbon). These data were analyzed using statistical techniques and cluster dendrograms for the definition of quimiofacies. The results allowed the definition of six quimiofacies which are described in compositional and parametric terms. These facies were determined by the type of organic matter and the paleo environmental conditions of deposit. These chemo facies are positively correlated with organofacies described in previous works. The chemofacies 1 is associated with the best inputs of organic matter and higher contents of the elements S, V, Ni and Co. The Co/Ni ratio shows that the organic matter is predominantly of marine origin and the parameter V/Ni indicates that this organic matter was deposited under anoxic to disoxic conditions.
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The impact of very accurate mapping of shallow velocity layers, determined by combining surface and refracted waves on static corrections. An example from the Llanos Basin, Eastern Colombia, SA
Authors German Rodriguez, Ingrid Tello, Ivan Hernandez, Wilmer Galindo and Jose JaramilloEstimating an accurate P-wave velocity of near-surface subsoil is necessary for reliable static corrections of reflection data used in seismic exploration, crucial for exploration surveys of areas with very low relief structures less than 25 milliseconds like Sub Andean Llanos basin, in Eastern Colombia. We found that combining Raleigh wave inversion together with P wave refraction tomography give us a very precise subsurface layered model that is quite useful for accurate static correction. To carry out this subsurface model, seismic data was acquired using a multi-channel seismograph, with 10-Hz Geospace GS-One geophones, and low-power explosive charges that acted as the seismic source. The seismic data was collected at a sample interval of 1 millisecond, and a trace length of 1000 milliseconds. Following the seismic data acquisition, the first breaks of the refracted wave were picked and inverted to obtain a refraction tomography through an iterative process of ray tracing and smooth inversion. The refraction tomography provided a P-wave velocity model of the subsoil to a depth of 10 meters approximately. Once the refraction tomography was obtained, the S wave profile was estimated by generating overtone images, which are cross plots of phase-velocities and frequencies of surface waves, usually considered as noise and filtered from the data. Each overtone image was picked to extract dispersion curves, and inverted together with the P-wave velocity model to obtain an S-wave velocity model. Some results obtained from data acquired and processed by GMAS are included.
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Reevaluación de los sistemas petrolíferos en la cuenca guajira offshore en Colombia, con base en geoquímica de alta resolución en muestras de fondo marino y modelamiento de cuenca
Authors Victor Ramirez, Luz Stella Vargas and Cesar MoraDebido a una combinación de factores donde se destacan las características de la acumulación de gas presente en los campos Chuchupa y Ballena (metano isotópicamente muy liviano), la cuenca Guajira Offshore fue considerada durante varias décadas como una cuenca casi exclusiva para el desarrollo de un play de gas biogénico. Estudios realizados por Ecopetrol durante la última década y especialmente la aplicación de métodos de geoquímica de alta resolución en muestras de fondo marino, han permitido reevaluar los sistemas petrolíferos de esta cuenca, permitiendo proponer la existencia de sistemas petrolíferos termogénicos donde probablemente existen varios intervalos generadores, incluyendo rocas cretácicas, los cuales alcanzaron un alto grado de evolución térmica en las zonas más profundas de la cuenca. De acuerdo con el tipo de fluidos caracterizados geoquímicamente en las muestras de fondo marino es posible identificar diferentes tipos de hidrocarburos que incluyen gas metano termogénico, gases húmedos, condensados y crudos tipo black oil. Los resultados del modelamiento de cuenca indican que estos hidrocarburos migraron a través de la cuenca durante el periodo Mioceno Medio a Tardío hasta alcanzar posiciones como las de las acumulaciones de Chuchupa y Ballena. La aplicación de este modelo en la cuenca Guajira Offshore, permite ampliar de forma significativa las expectativas exploratorias y convierte a esta cuenca en una de los sectores de exploración frontera más atractivos de Colombia.
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First Successful Fracturing Application in Unconventional Gas Reservoir in Colombia: Field Case
Authors Rudyard Vega, Ivan Leyva, Luis Francisco Rojas, Augustin De Fex, Claudio Navarro and Karen SinzaColombia’s oil industry has been on a rapid development over the past couple of years, and foreseeing the upcoming challenges for production maintenance the E&P companies have driven their efforts towards discovering and developing in unconventional formations. The Porquero formation (Lower to Middle Miocene), located in the Lower Magdalena Basin, consists of deepwater massive shales and shaly sandstones. In late 2010, the operator company (Pacific Rubiales Energy (PRE)) drilled the Well A-1X having as exploration target gas condensate in the Porquero formation in the Plato sub-basin in the Lower Magdalena. This paper goes through the process in which the Well A-1X well was evaluated and considered to be a candidate for Hydraulic Fracturing, the design process and analysis of the complexity of the Porquero formation, and finally the execution of the first Hydraulic Fracture in an unconventional, high-shale, low-perm gas sand formation in Colombia. The pilot hydraulic fracture was an economical approach to test the Porquero formation and estimate their productivity and reserves; a post-fracture 4-day well test showed PI improvement of 300% (3 times). This pilot frac job was carried only on one of four perforated intervals. Its successful development opens an opportunity to evolve into more complex completions such as multistage fracturing and horizontal well development for the field.
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El Campo Moqueta, primer descubrimiento en el piedemonte de la Cuenca del Putumayo
Authors Carlos Ramirez, Arlex Gutierrez and Frank SolanoEl campo Moqueto está localizado al norte de la cuenca del Putumayo, 6 km al NE del Campo Costayaco, descubierto en 2007 por Gran Tierra Energy. A partir de este descubrimiento se adquirio el programa sísmico Chaza 3D, donde se visualizó e interpreto parte de la estructura subthrust de Moqueta.
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C-isotope age constrains of aptian marine extension and oceanic anoxia in northern colombia: implications for the cretaceous caribbean oil system
The C-isotope stratigraphy of mixed siliciclastic-carbonate fossiliferous strata cropping out to in the southwestern flank of the Sierra Nevada de Santa Marta is reported. A pronounced positive C-isotope excursion of up to 7‰ suggests a lower Aptian (ca 123 Ma) depositional age. The mixed carbonate-siliciclastic successions concordantly overlay basaltic volcanics from the Guatapuri Formation. We relate the published 125 Ma K-Ar ages of such volcanics and the depositional age of the studied successions to an extensional event, followed by rapid tectonic stabilization and platform deposition. The pronounced positive C-isotope excursion is a global feature displayed by marine sediments deposited during a global oceanic anoxic event (OAE1). As the OAE1 would have favored the preservation and deposition of organic matter in the global oceans substrates, the studied sedimentary successions may be considered as a potential hydrocarbon-generating unit. The proposed age ultimately precludes the correlation of the studied successions with other hydrocarbon generating units in northern Colombia (e.g. The Cogollo Group and the La Luna Formation). The inferred depositional age and the occurrence of the OAE1 may also be considered when planning future oil exploration programs in the northern Colombian basins. This work highlights the use of stable C isotope chemostratigraphy for identification of cretaceous oil source rocks in NW South America and the Caribbean.
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Modelamiento Espacial de Geoquímica de gases en superficie y de Pozos Exploratorios en el Bloque Chaza, Putumayo Colombia
Authors Maria Quiroga, Carmen Neufeld and Joel MartinezLa separación de anomalías en datos geoquímicos de su entorno en superficie, constituye un punto crucial en cualquier investigación de prospección geoquímica desarrollada para la identificación de potencial acumulación de elementos químicos. Esta investigación revela la relación que existe espacialmente entre los datos de gases de subsuelo con aquellos muestreados en superficie para el bloque Chaza en Putumayo, Colombia. De los 83 gases muestreados en 301 puntos sobre la superficie, solamente los 6 que corresponden a las mayores concentraciones en las cromatografías de los 30 pozos existentes en la zona de estudio fueron incluidos en el análisis espacial (C2, C3, iC4, iC5, nC5) geoestadístico, al igual que las fallas principales de la zona de estudio y la columna estratigráfica presente en la zona.
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Cartografía geológica del límite de la cuenca Tumaco en las planchas 340, 362, 385 y 409
Authors Alejandro Pinilla Ocampo, Fuquen Naranjo and Deisy MilenaEl reconocimiento detallado de las unidades de basamento y cobertera sedimentaria en el sector sur de la Cordillera Occidental, específicamente en las planchas (escala 1:100000) 340, 362, 385 y 409 permitió delimitar dentro del basamento cristalino al Grupo Dagua, Grupo Diabásico Ultrmafitas de Guapi, Complejo Estructural de Timbiquí, Gabronorita de Nulpi y Granodiorita de Piedrancha. Las dataciones U-Pb y los análisis litogeoquimicos permiten reconocer dos eventos tectonomagmaticos en el Eoceno Medio y en el Mioceno Medio en las rocas que constituyen el basamento de la cuenca.
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Estratigrafia de la Secuencia Cretacica en el Campo Costayaco, Cuenca Putumayo, Colombia
Authors Carlos Ramirez, Arlex Guiterrez and Adriana HenaoEl Campo Costayaco fue descubierto en el 2007 por Gran Tierra Energy, siendo el mayor productor actual de hidrocarburo en la cuenca del Putumayo y el segundo campo más extenso después del Campo Orito. La estratigrafía del campo consta de una secuencia Cretácica marina de aproximadamente 1250' de shales, micrítas, biomicrítas y areniscas cuarzosas. Con base en la información de 14 pozos perforados, 3 núcleos recuperados, y la información disponible tanto de registros eléctricos, como de información sísmica 3D, se han determinado 11 unidades litológicas informales en la Formación Villeta y 3 para la Formación Caballos. La Arenisca T de la Formacion Villeta y la Formación Caballos son los principales yacimientos del campo, los cuales tienen características estratigráficas y sedimentológicas particulares. La integración de registros y análisis detallados de núcleos permitieron la interpretación de los diferentes ambientes de depósito de cada una de las unidades reservorio.
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